# Appendix A-2:

2007 Emissions Inventory

Documentation

# [This page intentionally left blank.]

# Development of the Point Source

Emission Inventory for 2007

in the SESARM Region

(Version 1.10a)

Prepared for:

John Hornback

Executive Director, Southeastern St ates Air Resource Managers, Inc.

526 Forest Parkway, Suite F

Forest Park, GA 30297-6140.

(404) 361-4000, FAX (404) 361-2411

hornback@metro4-sesarm.org

Prepared by:

AMEC E&I, Inc.

404 SW 140 th 

# Terrace

Newberry, FL 32669

(352) 333-6617, FAX (352) 333-6622

wrbarnard@ AMEC.com

Mark Diblin

Senior Principal William R. Barnard

Senior Principal



# AMEC Project No.: 6066-09-0326.02

Contract No.: S-2009-06-02

March 27, 2012

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

i AMEC 

# Table of Contents

1.0 ANNUAL 2007 INVENTORY FOR POINT SOURCES .......................................................... 1

1.1 INTRODUCTION .............................................................................................................. . 1

1.2 INITIAL DATA SOURCES AND QA REVIEW .................................................................... 2

1.2.1 State Submittals and Conversion into a NIF Database ............................................. 2

1.2.1.1 Alabama ............................................................................................................... . 5

1.2.1.2 Alabama – Jefferson County ................................................................................. 5

1.2.1.3 Florida ............................................................................................................... .... 6

1.2.1.4 Georgia ............................................................................................................... ... 6

1.2.1.5 Kentucky .............................................................................................................. .. 6

1.2.1.6 Kentucky – Jefferson County................................................................................. 6

1.2.1.7 Mississippi ........................................................................................................... .. 7

1.2.1.8 North Carolina ....................................................................................................... 7

1.2.1.9 North Carolina – Buncombe County ...................................................................... 7

1.2.1.10 North Carolina – Forsyth County ....................................................................... 8

1.2.1.11 North Carolina – Mecklenburg County .............................................................. 8

1.2.1.12 South Carolina ................................................................................................... 9

1.2.1.13 Tennessee ....................................................................................................... 10

1.2.1.14 Tennessee – Davidson County ....................................................................... 10

1.2.1.15 Tennessee – Hamilton County ........................................................................ 10

1.2.1.16 Tennessee – Knox County .............................................................................. 10

1.2.1.17 Tennessee – Shelby County ........................................................................... 10

1.2.1.18 Virginia ............................................................................................................. 11

1.2.1.19 West Virginia ................................................................................................... 11

1.3 EPA CAMD HOURLY EMISSION DATA ......................................................................... 11

1.4 PM AUGMENTATION ..................................................................................................... 12

1.4.1 Initial QA and Remediation of PM Pollutants .......................................................... 14

1.4.2 Updating of PM Factor Ratios ................................................................................. 15

1.4.3 PM Emission Calculations ....................................................................................... 15

1.4.4 PM Emission Results .............................................................................................. 17

1.5 EMISSION RELEASE POINT QA CHECKS .................................................................... 18

1.5.1 QA Checks and Gap-Filling for Location Coordinates ............................................. 18

1.5.2 QA Checks and Gap-Filling for Emission Release Parameters .............................. 19

1.6 STATE REVIEW OF INITIAL VERSION .......................................................................... 22

1.6.1 Alabama .................................................................................................................. 22

1.6.2 Alabama – Jefferson County ................................................................................... 22

1.6.3 Florida ..................................................................................................................... 2 2

1.6.4 Georgia .................................................................................................................... 23

1.6.5 Kentucky .................................................................................................................. 24

1.6.6 Kentucky – Jefferson County .................................................................................. 25

1.6.7 Mississippi ............................................................................................................... 25

1.6.8 North Carolina ......................................................................................................... 25

1.6.9 North Carolina – Buncombe County ........................................................................ 26

1.6.10 North Carolina – Forsyth County ......................................................................... 26

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# 1.6.11 North Carolina – Mecklenburg County ................................................................ 26

1.6.12 South Carolina ..................................................................................................... 26

1.6.13 Tennessee ........................................................................................................... 27

1.6.14 Tennessee – Davidson County ........................................................................... 28

1.6.15 Tennessee – Hamilton County ............................................................................ 28

1.6.16 Tennessee – Knox County .................................................................................. 28

1.6.17 Tennessee – Shelby County ............................................................................... 28

1.6.18 Virginia ................................................................................................................ 28

1.6.19 West Virginia ....................................................................................................... 29

1.7 STAKEHOLDER REVIEW .............................................................................................. 29

1.7.1 Alabama .................................................................................................................. 29

1.7.2 Florida ..................................................................................................................... 2 9

1.7.3 Georgia .................................................................................................................... 30

1.7.4 Kentucky .................................................................................................................. 30

1.7.5 North Carolina ......................................................................................................... 30

1.7.6 Tennessee ............................................................................................................... 30

1.8 IDENTIFICATION OF EGU AND NONEGU POINT SOURCES ...................................... 30

1.9 FINAL S/L AGENCY QA REVIEW ................................................................................... 31

1.9.1 Kentucky .................................................................................................................. 32

1.9.2 North Carolina ......................................................................................................... 32

1.9.3 North Carolina – Forsyth County ............................................................................. 32

1.9.4 South Carolina ......................................................................................................... 32

1.9.5 Virginia .................................................................................................................... 3 2

1.9.6 West Virginia ........................................................................................................... 32

1.10 2007 POINT SOURCE EMISSION SUMMARY ........................................................... 70

1.11 DATA FILES ................................................................................................................ 79

1.12 REFERENCES ............................................................................................................ 80

List of Exhibits

Exhibit 1 – Summary of Initial Point Source Submittals

Exhibit 2 – PM Compound Descriptions

Exhibit 3 – PM Compounds Reported in Initial State Submittals

Exhibit 4 – PM Cases and Steps Required to Augment PM Emissions

Exhibit 5 – Comparison of PM Emissions from the Init ial S/L Data Submittals and Version 1.1 of

the SEMAP 2007 Point Source Inventory

Exhibit 6 – Stack Parameter Data Replacement Matrix

Exhibit 7 – 2002 and 2007 Point Source CO Emissions by State

Exhibit 8 – 2007 Point Source CO Emissions by Category

Exhibit 9 – 2002 and 2007 Point Source NH 3 

# Emissions by State

Exhibit 10 – 2007 Point Source NH 3 

# Emissions by Category

Exhibit 11 – 2002 and 2007 Point Source NOx Emissions by State

Exhibit 12 – 2007 Point Source NO

x 

# Emissions by Category

Exhibit 13 – 2002 and 2007 Point Source PM10-PRI Emissions by State

Exhibit 14 – 2007 Point Source PM10-PRI Emissions by Category

Exhibit 15 – 2002 and 2007 Point Source PM25-PRI Emissions by State

Exhibit 16 – 2007 Point Source PM25-PRI Emissions by Category

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# Exhibit 17 – 2002 and 2007 Point Source SO2 Emissions by State

Exhibit 18 – 2007 Point Source SO2 Emissions by Category

Exhibit 19 – 2002 and 2007 Point Source VOC Emissions by State

Exhibit 20 – 2007 Point Source VOC Emissions by Category

List of Acronyms and Abbreviations

Acronym Description

AMEC 

# AMEC Environment & Infrastructure, Inc.

CAMD Clean Air Markets Division of EPA

CAP Criteria Air Pollutant

CEM Continuous Emission Monitoring System

CE Control Equipment (NIF table)

CERR Consolidated Emission Reporting Rule

CO Carbon Monoxide

EGU Electric Generating Unit

EM Emission (NIF table)

EP Emission Process (NIF table)

EPA U.S. Environmental Protection Agency

ER Emission Release (NIF table)

EU Emission Unit (NIF table)

LATLON Latitude / Longitude

MANE-VU Mid-Atlantic/Northeast Visibility Union

MARAMA Mid-Atlantic Regional Air Management Association

NAAQS National Ambient Air Quality Standards

NEI National Emission Inventory

NH 3 

# Ammonia

NIF3.0 National Emission Inventory Input Format Version 3.0

nonEGU Non Electric Generating Unit

NO

x 

# Oxides of Nitrogen

PE Period (NIF table)

PM Particulate Matter

PM-CON Primary PM, Condensable portion only (all < 1 micron)

PM-FIL Primary PM, Filterable portion only

PM-PRI Primary PM, includes filterables and condensables

PM-PRI= PM-FIL + PM-CON

PM10-FIL Primary PM10, Filterable portion only

PM10-PRI Primary PM10, includes filterables and condensables,

PM10- PRI = PM0-FIL + PM-CON

PM25-FIL Primary PM 2.5 

# , Filterable portion only

PM25-PRI Primary PM 2.5 

# , includes filterables and condensables

PM25-PRI= PM25-FIL + PM-CON

QA Quality Assurance

QAPP Quality Assurance Project Plan

SCC Source Classification Code

SEMAP Southeastern Modeling, Analysis, and Planning

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# Acronym Description

SESARM Southeastern State Air Resource Managers, Inc.

SMOKE Sparse Matrix Operator Ke rnel Emissions (modeling system)

SI Site (NIF Table)

SIC Standard Industrial Classification code

SIP State Implementation Plan

S/L State/Local

SO

2 

# Sulfur Dioxide

TR Transaction (NIF Table)

TSD Technical Support Document

UTM Universal TransMercator

VISTAS Visibility Improvement State and Tribal Association of the Southeast

VOC Volatile Organic Compounds

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AMEC Project No.: 6066-09-0326.02 January 18, 2012

1 AMEC 

# 1.0 ANNUAL 2007 INVENTO RY FOR POINT SOURCES

1.1 INTRODUCTION

In 2009, the 

# Southeastern State Air Resource Managers, Inc. ( SESARM) initiated a new

Southeastern Modeling, Analysis , and Planning (SEMAP) project. The SEMAP project addresses

the next phase of ozone, fine par ticle, and regional haze assessm ent obligations through funding

from two grants awarded by the U.S. Environmental Protection Agency (EPA).

This technical support document (TSD) explains the data sour ces, methods, and results for

preparing the 2007 criteria air pollutant (CAP) and ammonia ( 

# NH 3 

# ) emission inventory for point

sources for the Southeastern U.S. The region includes Alabama, Florida, Georgia, Kentucky,

Mississippi, North Carolina, South Carolina, Tenness ee, Virginia, and West Virginia. In general, point

sources in this inventory are sources classifi ed as major sources under the Title V permitting

program and sources required to submit hourly emissions data to EPA under various Clean Air Act

programs. Some State and local agencies included sma ller sources in the point source inventory.

The inventory includes annual em issions for sulfur dioxide ( 

# SO

2 

# ), oxides of nitrogen ( 

# NO

x 

# ), volatile

organic compounds (VOC), carbon monoxide (CO), ammonia ( 

# NH 3 

# ), and five components of

particulate matter (PM).

The inventory also includes particulate matte r (PM) emissions, cat egorized as filterable,

condensable, or total. Filterable emissions are generally considered to be the particles that are

trapped by the glass fiber filter in the front half of a Reference Method 5 or Method 17 sampling train.

Vapors and particles less than 0.3 microns pass thr ough the filter. Condensable particulate matter is

material that is emitted in the vapor state which later c ondenses to form homogeneous and/or

heterogeneous aerosol particles. The PM species in the inventory are categorized as: all filterable

and condensable particles with an aerodynamic diamet er less than or equal to a nominal 10 and 2.5

micrometers (i.e., PM10-PRI and PM25-PRI); filterabl e particles with an aerodynamic diameter less

than or equal to a nominal 10 and 2.5 microm eters (i.e., PM10-FIL and PM25-FIL); and condensable

particles (PM-CON). Note that PM10-PRI equa ls the sum of PM10-FIL and PM-CON, and PM25-

PRI equals the sum of PM25-FIL and PM-CON.

The EPA has provided guidance on developing emi ssion inventories to be used with models and

other analyses for demonstrating a ttainment of air quality goals for ozone, fine particles, and regional

haze (EPA 2005, EPA 2007). According to the EPA guidance, there are potentially two different

base year emissions inventories. One is the base case inventory which represents the actual

emissions for the meteorological period that is bei ng modeled. This inventory is generally used for

model performance evaluations. The second potential base year in ventory is called the baseline

inventory, which is generally used as the basis for projecting emissi ons to the future. The base case

inventory may include day specific information (e.g. hourly continuous emission monitoring data for

point sources) that USEPA consider s not appropriate for using in future year projections. Therefore,

the baseline inventory may need to replace the day spec ific emissions with average or “typical”

emissions (for certain types of sources). Howe ver, while a “typical” EGU inventory was prepared

and submitted to SEMAP for review and comment, it was never finalized. As a consequence, for the

2007 SEMAP point source inventory, the base case and baseline inventories are one in the same.

As indicated above, a “typical” year inventory for EGU sources was prepared as part of the base

year point source development effort. That inve ntory was provided to the states for review, but

AMEC never received any comments back from that review. Thus the “typic al” EGU inventory was

never finalized or put into NIF format. The inventory contai ned 3-year average SO 2 

# , NO

x 

# , and heat

input for each unit that reports data to CAMD.

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# The inventory went through several rounds of qu ality assurance (QA) reviews by State and local

(S/L) agencies, as well as a revi ew by stakeholders. Numerous co rrections and improvements were

made to the inventory. Updated ve rsions of the inventory were re leased throughout the inventory

development process to facilitat e S/L agency and stakeholder review. The following summarizes the

different versions of the inventory:

 Version 1.1, released April 201 0. S/L agency submittals were compiled into this initial

version of the inventory, em issions for units reporting to EPA’s Clean Air Markets Division

(CAMD) were analyzed, and the PM emissions we re augmented to provide a complete set of

PM species. Sections 1.2, 1.3, and 1.4 of this report de scribe the work done to prepare

Version 1.1.

 Version 1.2, not released. This version was used internally and included updates to stack

parameters as described in Section 1.5 of this report.

 Version 1.3, released May 18, 2010. This version contained the updat es and corrections to

the inventory specified by S/L agencies as described in Section 1.6. This version was

released for Stakeholder review.

 Version 1.4, not released. Th is version was used internally and included updates to classify

units into electric generating units (EGUs) and nonEGUs according to the classification

scheme discussed in Section 1.7. It also included updates and co rrections based upon

stakeholder review, as well as additional review by S/L agencies, as described in

Section 1.8.

 Version 1.5, released Septem ber 2, 2010. This version removed extraneous or incomplete

information that was not needed for air quality m odeling, such as emissions of hazardous air

pollutants and emissions for non-annual averagi ng times. This version was provided to

SEMAP for use in preparing emi ssion density maps and bubble plot s that were provided to

S/L agencies for final QA of sour ce locations and emission values.

 Version 1.6, released October 20, 2010. This version in cluded updates provided by S/L

agencies after their review of the em ission density maps and bubble plots.

 Version 1.7, released Decem ber 7, 2010. This version in cluded emission updates to two

facilities in Kentucky and replaced geographic c oordinates with latit ude and longitude for all

sources (in previous versions, the ge ographic coordinates were a mixture of

latitude/longitude and UTM coordi nates, depending on the agency).

 Version 1.8, released J anuary 26, 2001. This versio n included revisions to the

documentation and data files to respond to comments from EPA Region 4 dated November

10, 2011. The main revision to the data files was to delete facilities in North Carolina that

had permanently shutdown prior to 2007 but were inadvertently included in the 2007

inventory with non-zero emissions.

State-level emission summaries of the 2007 point sour ce inventory, referred to as Version 1.10a are

provided in Section 1.10. Final deliver ables are described in Section 1.11.

1.2 INITIAL DATA SOURCES AND QA REVIEW

Version 1.1 of the 2007 poi nt source inventory was developed using data submitt ed by State and

local agencies in the region, as well as data from the CAMD hourly emissi on monitoring database.

1.2.1 State Submittals and C onversion into a NIF Database

Each S/L agency collects point s ource data according to EPA approv ed procedures t hat are included

in each State’s point source emission inventor y quality assurance project plan with accompanying

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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3 AMEC 

# standard operating procedures. These plans and pr ocedures are updated on a continuing basis and

are available upon request.

States were requested to submit 2007 data for those major sources that they would normally submit

to EPA during the 3-year requirements of the Cons olidated Emission Reporting Rule (CERR). Some

S/L agencies were able to submit a complete set of data representing 2007. Other S/L agencies

were only able to submit 2007 data for very large sour ces. In this case, in ventories for other years

were used to create a complete 2007 point source inventory. In a few other cases, the S/L agency

submittal was supplemented with data from EPA’s 2005-based modeling platfo rm (EPA 2009c). S/L

agencies prepare point source emission inventory file s in a variety of formats – some use the NEI

Input Format (NIF) while others used different form ats. Exhibit 1 summarizes the data sources and

formats for the S/L agency point s ource submittals with additional ex planatory notes provided in the

following sections.

As noted in Exhibit 1, a few S/L agencies provi ded emissions data for a year other than 2007.

Georgia was the only State that requested that a linear projection from 2005/2008 to 2007 be made

when both 2005 and 2008 were available. There result of this interpolation for Georgia showed that

for sources where 2007 were not available, the emissions c hanged very little between 2005 and

2007. Other S/L agencies indicat ed that 2005, 2006, or 2008 emissi ons data should be considered

representative of 2007 for modeling purposes. This recommendation appears to be reasonable,

given the small amount of emissi ons associated with the facilities where 2007 were not available

(i.e., 97 percent of the point source 

# NO

x 

# emissions and 99 percent of the 

# SO

2 

# emissions are 2007

data). It was decided that spending limited resource s to obtain and apply appropriate growth factors

to project these emissions from 2005/2006/2008 to 2007 would provide an almost unnoticeable

improvement to the SEMAP 2007 inventory.

Also note that some S/L agencies submitted many more facilities than were included in the 2002

VISTAS inventory, while others s ubmitted fewer facilities. An ex planation of t he reason why the

number of facilities differs between 2002 and 2007 is provided fo r each S/L agency in the following

sub-sections. SESARM’s area sour ce contractor has developed proc edures to reconcile the point

and area source inventories to both (1) ensure that emissions minor point sources that are included

the point source inventory are not double counted in the area s ource inventory and (2) that

emissions from minor point source sources that ar e not in the point source inventory are included in

the area source inventory.

After the each S/L submittal was formatted in to a standard NIF database, AMEC Environment &

Infrastructure, Inc. (AMEC) perf ormed an initial review of the S/L inventories using EPA’s Basic

Format and Content Checker tool (EPA 2004). The tool was used to verify the data was in the

correct format, to check for referential integrity and duplicate record issues, and to check certain

fields for proper valid codes and ranges. Only mi nor issues were identified and were resolved by

AMEC without the need for assistanc e from the S/L agencies. Following this initial QA review, these

individual inventory files were c onsolidated into a single data set. A dditional QA acti vities identified

in the Quality Assurance Project Plan (SESAR M 2009) were carried out and documented in the

remainder of this document.

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# Exhibit 1 – Summary of Point Source Data Sources

Agency # of

Facilities in

VISTAS 2002

Inventory # of Facilities

in SEMAP

2007 V_1.10a

Inventory Submittal

Format Data Used for 2007 Inventory

AL 319 909 NIF ACCESS 2007 data for 328 major facilities;

2007 data for 613 minor facilities;

32 facilities had only HAP emissions

and were removed from the 2007

CAP inventory

AL

Jefferson 243 237 NIF ACCESS 2007 data for 37 very large facilities;

2005 S/L data for 237 facilities,

which also included the 37 very

large facilities

FL 1,050 1,136 NIF Text 2007 data for 1,136 facilities

GA 234 268 NIF ACCESS 2007 S/L data for 74 facilities

2007 CAMD data for 19 facilities not

in S/L submittal

2008 S/L data for 109 additional

facilities

2005 S/L data for 66 additional

facilities

KY 1,581 2,306 NIF xml 2007 data for 2,780 facilities

474 facilities had only HAP

emissions and were removed from

the 2007 CAP inventory

781 facilities were included in the

2007 SEMAP inventory but were not

included in the 2002 VISTAS

inventory

KY

Jefferson 76 155 NIF ACCESS 2007 data for 155 facilities

MS 640 282 NIF Text 2007 data for 46 facilities

2005 NEI data for 236 facilities

NC 994 1,908 ORL xls 2007 data for 2,145 facilities

See Section 1.1.1.8 for more

information regarding the increase in

the number of facilities

NC

Buncombe 6 64 NIF ACCESS 2007 data for 9 Title V facilities

2006 S/L data 64 facilities, which

also included the 9 Title V facilities

NC

Forsyth 30 82 EIS ACCESS 2007/08 data for 82 facilities

See Section 1.9.3 for discussion

NC

Mecklenburg 242 221 Quasi-ORL

xls 2007 data for 221 facilities

SC 802 291 NIF xml 2007 data for 291 facilities

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# Agency # of

Facilities in

VISTAS 2002

Inventory # of Facilities

in SEMAP

2007 V_1.10a

Inventory Submittal

Format Data Used for 2007 Inventory

TN 373 232 NIF xls 2007 data for 166 Type A and other

facilities

2005 NEI data for 66 facilities

TN

Davidson 201 205 NIF Text 2007 data for 205 facilities

TN

Hamilton 220 177 Quasi-ORL

xls 2007 data for 177 facilities

TN

Knox 11 8 NIF ACCESS 2007 data for 8 facilities

TN

Shelby 35 29 NIF xls 2008 S/L data for 29 facilities

VA 762 801 NIF ACCESS 2007 data for 801 facilities

WV 192 177 NIF ACCESS 2007 data for 177 facilities



# 1.2.1.1 Alabama

Alabama’s initial submittal contai ned two National Emission Invent ory (NEI) Input Format (NIF)

ACCESS database files. The first contained 2007 emissions data fo r 328 major sources, while the

second contained 2007 emission data for 613 minor s ources. AMEC merged the major source file

with the minor source found and iden tified 10 facilities that were in bot h files. We used the data from

the 2007 major source file and deleted the data from the minor source file to ensure that there was

no double counting of emissions fo r these 10 facilities. Alabama ensured that the minor source

emissions that were included in the poi nt source file were not double c ounted in the area source file.

Another contractor reconciled the point and area source inventories and Alabama reviewed the

results on a per category basis to ensur e that double counti ng did not occur.

There were numerous records flagged for out-of-r ange values for stack parameters or location

coordinates, or inconsist encies between the flow rate and velocity. These cases are discussed later

in this document. A large increase in VOC and PM emissions from 2002 to 2007 was identified.

Alabama investigated this problem an d identified a serious problem in their data conversion process.

New Emission (EM) and Control Equipment (CE) tables were provided in May 2010 to correct this

problem.

1.2.1.2 Alabama – Jefferson County

Jefferson County submitted two NI F ACCESS database files. The first contained 2007 emissions

data for 37 very large sources, while the se cond contained 2005 emission data for 237 sources.

AMEC merged the 2007 very large source file with the 2005 file and identified that the 37 very large

facilities were in both files. We used the data from the 2007 file and deleted the corresponding

facilities from the 2005 file to ensure no double counting of emissi ons. AMEC did not project 2005

emission data to 2007, as the 2005 data was considered to be repr esentative of 2007.

Jefferson County submitted emissions data for a large number of hazardous air pollutants. Since

these pollutants are not needed for regional ozone and fine particle modeling, they were stripped

from the EM and CE tables.

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# The EPA’s Basic Format and Content Checker identif ied several relational widow/orphan issues.

These were caused by the Emission Unit ID and Emission Release Point ID being reversed in the

EP table for some records. AMEC made the nece ssary corrections to the NIF EP table to ensure

that all NIF EM records had a match in the NIF Emission Unit (EU), Emission Process (EP), and EM

tables.

The flow rates provided in the NIF Emission Rel ease (ER) table were reported in cubic feet per

minute. The NIF specificat ions require that this field be report ed in cubic feet per second. AMEC

recalculated the flow rate by dividing the flow rate provided by Jefferson County by 60.

1.2.1.3 Florida

Florida submitted NIF tables in ASC II text format with 2007 emissions data for 1,139 facilities. There

were numerous records flagged for out-of-range values for stack parameters or location coordinates,

or inconsistencies between the fl ow rate and velocity by t he EPA’s Basic Format and Content

Checker. These cases are discussed later in Se ction 1.5 of this docum ent. Otherwise the data

passed all of the QA checks.

1.2.1.4 Georgia

Georgia submitted three NIF ACCESS database file s. The first contai ned 2007 emissions data for

74 very large sources. The se cond file contained 20 08 emission data for 109 additional facilities.

And the third file contained 2005 dat a for 69 additional facilities. AMEC merged the three files using

the 2007 data when available, the 2008 data wher e 2007 data were not available, and 2005 data as

a last resort. We used the data from the 2007 f ile and deleted the corres ponding facilities from the

2008/2005 files to ensure no double count ing of emissions. No signific ant issues were identified by

EPA’s Basic Format and Content Checker. No proj ecting of 2005 emissions to 2007 or back casting

of 2008 emissions to 2007 was done during the initia l processing of the submittals. See Section

1.6.4 for a discussion of how 2007 emissions we re subsequently estimated for the final SEMAP

inventory when only 2005 or 2008 data were available.

1.2.1.5 Kentucky

Kentucky submitted an xml file that was loaded in to an ACCESS database with NIF tables with 2007

emissions data for 2,780 facilities. There were approximately 474 facilities in Kentucky’s submittal

that had only HAP emissions (i.e., emi ssions were zero for all criteria air pollutants at the facility) and

were removed from the 2007 inventory. An addi tional 781 facilities were included in the 2007

SEMAP inventory but were not includ ed in the 2002 VISTAS inventory. These additional facilities in

the 2007 SEMAP inventory were generally very small sources, and the aggregate 

# NO

x 

# emissions

from these 781 small facilities totaled only 805 tons per year.

The EPA’s Basic Format and Content Checker identifi ed several relational wi dow issues, that is,

there were SI, ER, EU, EP, PE and CE records with no corresponding emissions data in the EM file.

These widow records were removed from t he SI, ER, EU, EP, PE, and CE tables.

The flow rates provided in the ER table were reported in cubic feet per minute. The NIF

specifications require that this field be reported in cubic feet per second. AMEC recalculated the

flow rate by dividing the flow rate provided by Kentucky by 60.

There were numerous records flagged for out-of-r ange values for stack parameters or location

coordinates, or inconsistencies bet ween the flow rate and velocity by the EPA’s Basic Format and

Content Checker. These cases are discuss ed later in Section 1.5 of this document.

1.2.1.6 Kentucky – Jefferson County

Jefferson County submitted two NI F ACCESS databases cont aining 2007 emissions data – one file

contained criteria air pollutants and the other file cont ained hazardous air pollutants. Only the

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7 AMEC 

# criteria air pollutant file was processed. Jefferson Co unty’s submittal passed all of checks made by

the EPA’s Basic Format and Content Checker.

1.2.1.7 Mississippi

Mississippi submitted NIF tables in ASCII text fo rmat with 2007 emissions data for 45 facilities.

Mississippi’s submittal passed all of checks made by the EPA’s Basic Format and Content Checker.

Mississippi’s 2007 submittal was supplemented wi th data from EPA’s 2005-based modeling platform

(EPA 2009c). The data were provided in SMOKE ORL format, converted into a NIF database, and

merged with Mississippi’s submittal. We used t he data from Mississippi’s 2007 file and deleted the

corresponding facilities from the 2005 EPA file to ensure no double count ing of emissions.

Mississippi decided to include 236 facilities from the 2005 NEI from the 2007 SEMAP inventory. At

this time, AMEC did not perform any projecting of 2005 data to 2007. No si gnificant issues were

identified by EPA’s Basic Fo rmat and Content Checker.

1.2.1.8 North Carolina

North Carolina submitted a SMOKE one-record-per-line (ORL) file with 2007 data for 2,145 facilities.

AMEC converted the ORL file to a NIF database. There was no contro l information in the ORL file,

so we were not able to create a NIF CE table.

There were numerous records flagged for out-of-r ange values for stack parameters or location

coordinates, or inconsistencies bet ween the flow rate and velocity by the EPA’s Basic Format and

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the

data passed all of the QA checks.

A large increase in VOC emissions from 2002 to 2007 was identified. Nort h Carolina investigated

this problem and identified a serious problem in their data conversion proc ess. New EM and CE

tables were provided in May 2010 to correct this problem.

The 2007 SEMAP inventory contains many more s ources than were included in the 2002 VISTAS

inventory. There are three reasons to explain the large increase in the number of facilities in the

2007 inventory versus the 2002 inventory:

 There are some new permit sources added since 2002;

 There were about 163 facilities in NC’s init ial submittal that were permanently closed

between 2002 and 2006 that were inadvertently left in the 2007 inventory with non-zero

emissions. These facilities were remo ved from the 2007 SEMAP inventory; and

 Most the new facilities in 2007 are due to the following reason: 2002 was the year NC

changed the emission reporting system. From 1993 to 2002, all non-title V sources reported

their emission once every three years ( 1993, 1996, 1999, and 2002). Since 2002, NC

changed the emission reporting system from once ev ery three years to once every five year

and each facility reports their em ission the year their permit expired. So the 2007 point

source emission inventory is much more in clusive compared to 2002 emission inventory,

which only included the facilities reported during the year of 2002, not all facilities that

operated in 2002.

1.2.1.9 North Carolina – Buncombe County

Buncombe County submitt ed two NIF ACCESS database files. The first contai ned 2007 emissions

data for 9 Title V facilities, while the second c ontained 2006 emission data for 65 facilities. AMEC

merged the 2007 Title V source file with the 2006 file and verified that the 9 Title V facilities were in

both files. We used the data from the 2007 file for the Title V facilities and deleted the corresponding

facilities from the 2006 file to ensure no double count ing of emissions. We also deleted all records

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

8 AMEC 

# for Snider Tire (Facility ID 0861) which ceas ed operation in 2006 and did not operate in 2007.

AMEC did not project the 2006 emissions to 2007, as the 2006 emissions are considered to be

representative of 2007.

There were several records flagged for out-of-ra nge values for stack parameters or location

coordinates, or inconsistencies bet ween the flow rate and velocity by the EPA’s Basic Format and

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the

data passed all of the QA checks.

1.2.1.10 North Carolina – Forsyth County

Forsyth County provided 2008 data for 84 facilities in an EI S-formatted ACCESS database. The

data is actually a mix of 2008, 2007 and previous year data, but Fo rsyth County indi cated that the

submittal is representative of ca lendar year 2007. AMEC performed data reformatting a number of

data augmentation steps to create reasonably complete NIF tables, as follows:

 SI Table – relevant fields fr om the “FacilitySite” ACCESS table were mapped to NIF SI table

fields.

 ER Table – relevant fields from the “Rel easePoint” ACCESS table we re mapped to NIF ER

table fields. The flow rate in the “Release Poin t” table was in cubic feet per minute. The NIF

specifications require that this field be reported in cubic feet per second. AMEC recalculated

the flow rate by dividing the flow rate provi ded by 60. There were no stack-level geographic

coordinates in the “ReleasePoint Geographic Coordinates” ACCESS tabl e. However, there

were facility-level coordinate s for some facilities in the “FacilitySiteGeographicCoordinates”

ACCESS table, and these were used for all emission release points associated with the

facility. Where a facility matc h could not be made, we substitu ted the county centroid for the

geographic coordinates (longitude -80.24, latitude 36.114).

 EU Table – relevant fields from the “Emiss ionUnit” ACCESS table we re mapped to NIF EU

table fields.

 EP Table – relevant fields from the “Emiss ionProcess” ACCESS table were mapped to NIF

EP table fields. The emission release point identifier was obtained from the

“ReleasePointApportion ment” ACCESS table.

 PE Table – relevant fields from the “Emiss ionProcess” ACCESS table were mapped to NIF

PE table fields.

 CE Table – no information on control equipment was provided.

 EM Table – relevant fields from the “E missions” ACCESS table were mapped to NIF ER

table fields. The emission release point identifier was obtained from the

“ReleasePointApportion ment” ACCESS table.

There were several records flagged for out-of-ra nge values for stack parameters or location

coordinates, or inconsistencies bet ween the flow rate and velocity by the EPA’s Basic Format and

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the

data passed all of the QA checks.

1.2.1.11 North Carolina – Mecklenburg County

Mecklenburg County provided 2007 emi ssions data for 539 facilities in a spreadsheet t hat contained

a limited number of NIF fields. AMEC perfo rmed data reformatting and a number of data

augmentation steps to create reasonably complete NIF tables, as follows:

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

9 AMEC 

#  SI Table – only the facilit y id# and facility name were prov ided; we obtained the SIC code

from the VISTAS 2002 B&F inventory where we were able to match facilities.

 ER Table – the submittal did not contai n any stack parameters and the geographic

coordinates were in NC State Pl anar coordinates, not UTM coor dinates or latitude/longitude

as required by the NIF specification. To f ill in the geographic coor dinates, we obtained the

latitude and longitude from the VISTAS 2002 B&F inventory where we were able to match

facilities. Where a facility ma tch could not be made, we substituted the county centroid for

the geographic coordinates (longitu de -80.789, latitude 35.252). Stack parameters for the

Stage I gasoline distribution facilities were assig ned a fugitive release height of 10 feet.

Stack parameters for all other sources will be f illed in according to t he gap-filling procedures

discussed later in Section 1.5 of this document.

 EU Table – the submittal onl y contained the unit description, all other EU non-key data

elements were left blank.

 EP Table – the submittal only contained SCC and the proce ss description, all other EP nonkey data elements were left blank.

 PE Table – we filled in the PE table with t he PE key identifiers, and added the startdate of

20070101 and end date of 20071231. All other PE non-key data elements were left blank.

 CE Table – no control information was provided, so the CE table is blank.

 EM Table – the submittal c ontained annual emissions for all criteria air pollutants and

ammonia.

After reformatting the spreadsheet into NIF t ables, we ran the EPA’s Basic Format and Content

Checker and did not detect any QA issues other than the missing stack parameters.

Mecklenburg County initially included 319 Stage I gasoline stations in the point source inventory.

For consistency with other count ies in North Carolina (where Stage I emissions are included in the

area source inventory) and to avoid double counting, these gasoline stations were removed from the

point source inventory.

1.2.1.12 South Carolina

South Carolina submitted an xml f ile that was loaded into an ACCESS database with NIF tables with

2007 emissions data for 293 facilities.

The EPA’s Basic Format and Content Checker identif ied that certain EM records associated with

facility ID 2320-0034 (NAN YA Plastics) were assi gned to FIPS 45041 (Florenc e County) while other

NIF records associated with this plant were associated with FIPS 45089 (Williamsburg County).

AMEC changed the FIPS to 45089 for the records in t he EM table to resolve this orphan issue.

Geographic coordinates in the ER table were not changed.

The flow rates provided in the ER table were reported in cubic feet per minute. The NIF

specifications require that this field be reported in cubic feet per second. AMEC recalculated the

flow rate by dividing the flow rate provided by South Carolina by 60.

South Carolina’s 2007 submittal included many fe wer facilities than were in the VISTAS 2002

inventory. South Carolina revi ewed data from EPA’s 2005-based mode ling platform. South Carolina

decided that the sources that were included in the 2002 but not in the 2007 inventory were

predominantly minor sources, and that the use of EPA’s 2005 NEI data was not appropriate for use

in the 2007 SEMAP inventory.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

10 AMEC 

# 1.2.1.13 Tennessee

Tennessee submitted two spreadsheets with NIF tables for all counties except the four local program

counties. The first file cont ained 2007 emissions data for 45 very large sources (i.e., Type A

sources), while the second contai ned 2007 emission data for additional smaller facilities. AMEC

merged the two files and checked fo r duplicate facilities. One fac ility – JW Aluminum (Facility ID

47113-0010) – was found in both submittals. Only t he Type A submittal for this facility was used to

avoid double counting of emissions.

Tennessee submitted emissi ons data for a large number of hazar dous air pollutants. Since these

pollutants are not needed for regional ozone and fi ne particle modeling, they were stripped from the

EM and CE tables.

The EPA’s Basic Format and Content Checker identif ied several relational widow/orphan issues.

AMEC made the necessary corrections to the NIF t ables to ensure that all EM records had a match

in the EU, EP, PE and EM tables.

Tennessee’s 2007 submittals were supplement ed with data from EPA’s 2005-based modeling

platform. These data were download ed from EPA’s ftp site (file name:

2005v4CAPHAP_orl_point.zip). The data were prov ided in SMOKE ORL format, converted into a

NIF database, and merged with Tennessee’s submi ttal. We used the data from Tennessee’s 2007

files and deleted the corresponding facilities from t he 2005 EPA file to ensur e no double counting of

emissions. At this time, AMEC did not perform any projecting of 2005 data to 2007. No significant

issues were identified by EPA’s Basic Format a nd Content Checker. An additional 280 facilities

were added during this augmentation process.

1.2.1.14 Tennessee – Davidson County

Davidson County submitted NIF tables in ASCII text format with 2007 emissions data for

205 facilities. There were numerous records flagged for out-of-range values for stack parameters or

location coordinates, or inconsis tencies between the fl ow rate and velocity by the EPA’s Basic

Format and Content Checker. These cases are di scussed later in Section 1.5 of this document.

Otherwise the data passed all of the QA checks.

1.2.1.15 Tennessee – Hamilton County

Hamilton County provided data re presentative of 2007 for 177 fac ilities in a spreadsheet that

contained the NIF fields needed fo r regional air quality mode ling. AMEC performed data

reformatting to create reasonably complete NIF t ables. The data passed a ll of the QA checks.

1.2.1.16 Tennessee – Knox County

Knox County submitted a NIF A CCESS database containing 2007 emissions data for 9 facilities.

There were a few records flagged for out-of-ran ge values for stack parameters or location

coordinates, or inconsistencies bet ween the flow rate and velocity by the EPA’s Basic Format and

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the

data passed all of the QA checks.

1.2.1.17 Tennessee – Shelby County

Shelby County submitted a spreadsh eet with NIF tables for 29 fac ilities with 2008 emissions data.

The 2008 was consi dered representative of 2007 for all sources except the TVA Allen Plant (Facility

ID 47157-00528), for which we used the 2007 annual 

# SO

2 

# and 

# NO

x 

# emissions as reported in EPA’s

CAMD database.

Shelby County submitted emissions data for a la rge number of hazardous air pollutants. Since

these pollutants are not needed for regional ozone and fine particle modeling, they were stripped

from the EM and CE tables.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

11 AMEC 

# The EPA’s Basic Format and Content Checker identif ied several relational widow/orphan issues.

AMEC made the necessary corrections to the NIF t ables to ensure that all EM records had a match

in the EU, EP, PE and EM tables.

1.2.1.18 Virginia

Virginia submitted a NIF ACCESS database containing 2007 emissions data for 801 facilities. Since

Virginia is participating with MARAMA in de veloping a regional modeling inventory for the

northeastern States, Virginia’s data has already undergone considerable QA review and updating.

As part of the MARAMA inventory development pr ocess, Virginia provided emissions data for a

number of additional distributed gene ration units. Virginia’s submitta l to MARAMA was subjected to

the QA and PM augmentation procedures described in this report. Virginia has accepted the

MARAMA 2007 point source inventory for use in t he SEMAP 2007 point source modeling inventory.

1.2.1.19 West Virginia

West Virginia submitted a NIF ACCESS database containing 2007 emissions data fo r 177 facilities.

West Virginia’s submittal passed all of c hecks made by the EPA’s Basic Format and Content

Checker with the exception of so me of the stack parameter values . There were numerous records

flagged for out-of-range values for stack parameter s or location coordinates , or inconsistencies

between the flow rate and veloci ty by the EPA’s Basic Format and Content Checker. These cases

are discussed later in Sect ion 1.5 of this document.

1.3 EPA CAMD HOURLY EMISSION DATA

The second source of data was the hourly emission data reported to EPA by facilities to comply with

various provisions of the Cl ean Air Act. AMEC downloaded the 2007 CAMD annual inventory

containing 

# NO

x 

# and 

# SO

2 

# emissions, heat input dat a and other information from the CAMD web site

(EPA 2009a).

AMEC prepared an initial crosswalk file to match facilities and units in the CAMD inventory to

facilities and units in the 2007 SEMAP in ventory. In the CAMD invent ory, the Office of Regulatory

Information Systems (ORIS) i dentification (ID) c ode identifies unique facilities and the unit ID

identifies unique boilers and internal combustion engines (i.e., turbines and reciprocating engines).

AMEC also downloaded the 2007 CAMD hour ly inventory containing hourly 

# NO

x 

# and 

# SO

2 

# emissions

and heat input data from the CAMD website (EPA 2009b). AMEC summed the hourly emissions to

the annual level (or 6-month level for 6-month repo rting units) by emission unit. The summed hourly

data was compared to the annual summary data, whic h matched in virtually all case. This check was

made because SEMAP is considering using the actual 2007 hourly data rather than average

temporal profiles in the next round of regional air quality modeling.

As a starting point for developi ng the CAMD-to-NIF crosswalk, AMEC obtained and used the CAMDto-NIF crosswalk that was developed for the VISTAS Best & Final inventory (VISTAS, 2007). This

file was useful for matching many facilities and uni ts. However, in many other cases either the

CAMD unit identifier changed or t he facility and unit identifiers in the S/L database changed. For

example, the facility IDs in West Virginia’s 2002 VISTAS database we re a 4-digit field, while the

facility IDs in the 2007 SEMAP inventory are a 5-digit field. In Kentucky, the facility IDs in the 2002

VISTAS database consis ted of the five-digit FIPS code follow ed by a 5-digit facility ID, while the

facility IDs in the 2007 SEMAP inventor y consisted of only the 5-digit facility ID. In North Carolina,

nearly all unit IDs changed between 2002 and 2007.

AMEC prepared an Excel Workbook file for eac h S/L agency with linkages between the CAMD

identifiers and the S/L agency i dentifiers and a comparison betw een the CAMD annual summary

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

12 AMEC 

# emissions, the annual emissions summed from t he hourly CAMD database, and annual emissions

reported in the S/L inventory. This spreadshe et matched the CAMD unit-level IDs (ORISID and

UNITID) with corresponding NIF table IDs (FIPS, SITE ID, EU ID, EP ID, ER ID). Emissions were

shown as obtained from (1) the CAMD unit level f ile, (2) the sum of the CAMD hourly emission file,

and (3) the State submitted NIF tabl es. Note that the CAMD Emissi ons are reported at the unit level

while the NIF emissions are reported at the Unit/Process/Stack level.

AMEC added three fields to the NI F EP table to facilitate the link age to the CAMD database. We

added fields to store the CAMD ORISID, CAMD Unit ID, and CAMD number of reporting months.

AMEC prepared a CAMD-to-NIF crosswalk spreads heet for each State. S/L agencies were asked to

review this list and verify that (1) the linkages are correct, (2) there are no large sources missing

from the CAMD-to-NIF crosswalk, and (3) ther e are not any large discrepancies between the

emissions reported to CAMD and the emissi ons reported in the SEMAP database.

There are three types of possible linkages:

 CAMD facility has no match in NIF SI facilit y table. The emissions from these facilities

reported to CAMD are small, and initia lly accounted for about 0.5% of the 

# NO

x 

# and

0.07% of the 

# SO

2 

# emissions in the CAMD database.

 CAMD unit could not be matched in NIF. T he emissions from these facilities reported to

CAMD were small, accounti ng for about 0.9% of the 

# NO

x 

# and 0.007% of the 

# SO

2



# emissions in the CAMD database. Most of t he units that could not be matched at the unit

level are either peaking units or industrial sources such as paper mills or chemical plants.

In addition, there were several instances wher e multiple CAMD units match to a single

NIF record (i.e., units are grouped in the NIF t ables but reported individually in the CAMD

database).

 CAMD unit matches with a single NIF record or CAMD unit matches with multiple NIF

records (in many cases, the NIF tables include multiple records for different fuel types).

The emissions from these units reported to CAMD account for about 98.6% of the 

# NO

x



# and 99.9% of the 

# SO

2 

# emissions in the CAMD database. In most cases the sum of the

emissions from the matching NIF records are ge nerally very close to the CAMD unit level

emissions; and S/L agencies verified that linkages were correct.

As another QA check, AMEC comp iled a list of sources with EG U SCCs of 1-01-xxx-xx and 2-01-

xxx-xx in the S/L agency NIF tables that could not be linked to the CAMD CEM table to help resolve

some of the linkage issues noted above. S/L agencies made signifi cant efforts to improve the

crosswalk between the CAMD identif iers and the S/L agency identifiers.

1.4 PM AUGMENTATION

PM compounds may be reported in several forms, as identified in Exhibit 2. Exhibit 3 provides a

count of the number of a nnual NIF EM table records in each agency’s NIF Submittal by type of PM

compound. The PM augmentations process gap-fills missing PM pollutant complements. We

generated emission estimates for filterable and primary PM -2.5 

# , filterable and primary PM-10 and

condensable PM if emission estimate s for those species were missing from the S/L agency submittal

.For example, if a S/L agency provided only PM 10-PRI emissions, the PM augmentation process

filled in estimates for PM-CON, PM 10-FIL, PM25-PRI, and PM25-FIL.

The PM augmentation process is essentially the same process used in developing the 2002 VISTAS

Best and Final inventory and is virtually identic al to the EPA methodology used for the 2002 NEI

(EPA 2006a). The steps in the PM augment ation process were as follows:

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

13 AMEC 

#  Step 1: Initial QA and remediati on of S/L provided PM pollutants;

 Step 2: Updating of PM factor ratios prev iously developed for MARAMA based on factors

from the Factor Information and Retrieval Data System and the EPA PM Calculator;

 Step 3: Implementation of the ratios developed in step 2;

 Step 4: Presentation of PM augmentation results to S/L agencies for review and comment;

and

 Step 5: Updates to augmented values in ca ses where the S/L agency was able to obtain

source-specific data.

Exhibit 2 – PM Compound Descriptions

Pollutant

Code Pollutant Pollutant Description

PM-CON Primary PM

Condensable portion

only (all < 1 micron) Material that is vapor phase at stack conditions, but

which condenses and/or reacts upon cooling and

dilution in the ambient air to form solid or liquid PM

immediately after discharge from the stack.

PM-FIL Primary PM, Filterable

portion only Particles that are directly em itted by a source as a solid

or liquid at stack or release conditions and captured on

the filter of a stack test train.

PM-PRI Primary PM, includes

filterables and

condensables

PM-PRI=

PM-FIL + PM-CON Particles that enter the atmosphere as a direct

emission from a stack or an open source. It is

comprised of two components: Filterable PM and

Condensable PM.

PM10-FIL Primary PM10,

Filterable portion only Particles with an aerodynamic diameter equal to or less

than 10 micrometers that are directly emitted by a

source as a solid or liquid at stack or release conditions

and captured on the filter of a stack test train.

PM10-PRI Primary PM10,

includes filterables and

condensables,

PM10- PRI =

PM0-FIL + PM-CON Particles with an aerodynamic diameter equal to or less

than 10 micrometers that ent er the atmosphere as a

direct emission from a stack or an open source. It is

comprised of two components: Filterable PM and

Condensable PM. (As specified in § 51.15 (a)(2),

These two PM components are the components

measured by a stack sampling train such as EPA

Method 5.)

PM25-FIL Primary PM 2.5 

# , Filterable portion only Particles with an aerodynamic diameter equal to or less

than 2.5 micrometers that ar e directly emitted by a

source as a solid or liquid at stack or release conditions

and captured on the filter of a stack test train.

PM25-PRI Primary PM 2.5 

# , includes filterables and

condensables

PM25-PRI=

PM25-FIL + PM-CON Particles with an aerodynamic diameter equal to or less

than 2.5 micrometers that ent er the atmosphere as a

direct emission from a stack or an open source. It is

comprised of two components: Filterable PM and

Condensable PM. (As specified in § 51.15 (a)(2),

These two PM components are the components

measured by a stack sampling train such as EPA

Method 5.)

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

14 AMEC 

# Exhibit 3 – PM Compounds Reported in Initial State Submittals

Number of Annual EM Records in S/L Agency’s Initial NIF Submittal

Agency PMCON PMFIL PMPRI PM10-

FIL PM10-

PRI PM25-

FIL PM25-

PRI

AL 0 4,748 0 2,918 0 2,035 0

AL Jefferson 0 318 0 631 0 626 0

FL 0 3,576 0 3,672 0 0 0

GA 0 137 2,912 0 1,869 0 1,285

KY 0 0 29,856 0 29,859 0 99

KY Jefferson 20 0 222 20 222 20 214

MS 1 

# 413 56 3,073 429 3,251 429 3,251

NC 0 0 0 0 9,120 0 5,800

NC Buncombe 26 40 63 40 63 40 58

NC Forsyth 12 4 408 23 381 5 210

NC Mecklenburg 0 0 0 0 613 0 309

SC 1 

# 1,241 409 6,645 1,439 5,992 1,422 4,224

TN 1 

# 2,274 3,175 1,258 2,811 2,560 2,641 2,441

TN Davidson 0 0 0 0 775 0 649

TN Hamilton 0 0 394 0 279 0 332

TN Knox 0 0 0 0 15 0 1

TN Shelby 57 189 79 70 279 63 99

VA 2 

# 5,238 0 0 5,238 5,241 5,238 5,241

WV 167 2,138 802 1,814 737 1,586 691

1) Includes PM records from EPA’s 2005-based modeling inventory, which have already been

augmented by EPA



# 2) Virginia’s PM augmentation was previously perf ormed using an identical augmentation process

during the development of the 2007 regional em ission inventory for the Northeast/Mid-Atlantic

States



# 1.4.1 Initial QA and Remediation of PM Pollutants

Prior to executing the PM augmentation process, we first reviewed the data for inconsistencies. If

values are found to be inconsis tent, they were replaced. The consistency che cks and replacement

actions are as follows:

1. If PM10-PRI >0 and PM25-PRI > PM10-PR I (and PM10-FIL, PM25-FIL and PM-CON are

null or 0), then set PM25-PRI = PM10-PRI.

2. If PM10-FIL > 0 and PM25-FIL > PM10-FIL (and PM10-PRI, PM25-PRI and PM-CON are

null or 0), then set PM25-FIL = PM10-FIL.

3. If PM10-PRI >0 and PM10-FIL > PM10-PRI (and PM25-PRI, PM25-FIL and PM-CON are

null or 0), then set PM10-FIL = PM10-PRI.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

15 AMEC 

# 4. If PM25-PRI > 0 and PM25-FIL > PM25-PRI (and PM10-PRI, PM10-FIL and PM-CON are

null or 0), then set PM25-FIL = PM25-PRI.

The consistency checks revealed very few occurrences of inc onsistencies, and when

inconsistencies did occur, the emission values were very small. As a result, S/L agencies were not

asked to review this information and provide corr ections because the inconsistencies did not involve

significant emission sources. The replacement actions above were appropriate for an inventory

used for regional air quality modeling.

1.4.2 Updating of PM Factor Ratios

The augmentation steps require the use of ratios developed from available emissions and particle

size distribution data. These ratios are needed when only one PM term is available, and two or more

terms need to be augmented. Examples of how we used the PM ratios are shown below:

PM-FIL × RatioCON/FIL = PM-CON

PM-PRI × RatioCON/PRI = PM-CON

PM-CON × RatioFIL/CON = PM-FIL

PM-CON × RatioPRI/CON = PM-PRI

A table of PM compound ratios was developed utilizing the tabl e developed for the MANE-VU 2002

inventory (MARAMA, 2006). This table is keyed by SCC, primary contro l device, and secondary

control device and provides the ratios listed in the above equati ons. We updated this table to

include SCC, primary control device, and second ary control device codes found in the 2007 SEMAP

inventory that were not contai ned in the 2002 MANE-VU inventory.

1.4.3 PM Emission Calculations

The gap-filling requires that the data be analyzed and separate d into cases. The cases determine

which math steps and ratios of PM terms will be applied. Exhibi t 4 shows the various cases and the

augmentation method that was applied.

Exhibit 4 – PM Cases and Required St eps to Augment PM Emissions

Case PM Reported Augmentation Methodology

1 PM25-PRI PM-CON = PM25-PRI * CON_P25 ratio

PM25-FIL = PM25-PRI - PM-CON

PM10-FIL = PM25-FIL * F10_F25 ratio

PM10-PRI = PM-CON + PM10-FIL

2 PM10-PRI PM-CON = PM10-PRI * CON_P10 ratio

PM10-FIL = PM10-PRI - PM-CON

PM25-FIL = PM10-FIL / F10_F25 ratio

PM25-PRI = PM-CON + PM25-FIL

3 PM25-PRI

PM10-PRI PM-CON = PM10-PRI * CON_P10 ratio

PM10-FIL = PM10-PRI - PM-CON

PM25-FIL = PM25-PRI - PM-CON

4 PM10-FIL PM-CON = PM-CON * CON_F10 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-FIL = PM10-FIL / F10_F25 ratio

PM25-PRI = PM-CON + PM25-FIL

5 PM10-FIL

PM25-FIL PM-CON = PM10-FIL * CON_F10 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

16 AMEC 

# Case PM Reported Augmentation Methodology

6 PM10-FIL

PM10-PRI PM-CON = PM10-PRI - PM10-FIL

PM25-FIL = PM10-FIL * F25_F10 ratio

PM25-PRI = PM-CON + PM25-FIL

7 PM25-FIL PM-CON = PM25-FIL * CON_F25 ratio

PM10-FIL = PM25-FIL * F10-F25 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL

8 PM10-FIL

PM10-PRI

PM25-FIL

PM25-PRI PM-CON = PM25-PRI - PM25-FIL

9 PM-PRI PM-CON = PM-PRI * CON_PRI ratio

PM-FIL = PM-PRI - PM-CON

PM10-FIL = PM-FIL * F10_FIL ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-FIL = PM10-FIL / F10_F25 ratio

PM25-PRI = PM-CON + PM25-FIL

10 PM25-FIL

PM25-PRI PMCON = PM25-PRI - PM25-FIL

PM10-FIL = PM25-FIL * F10_F25 ratio

PM10-PRI = PM-CON + PM10-FIL

11 PM-CON

PM10-FIL

PM25-FIL PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL

12 PM-CON PM10-FIL = PM-CON * F10_CON ratio

PM25-FIL = PM10-FIL * F25_F10 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL

13 PM-CON

PM10-FIL

PM10-PRI PM25-FIL = PM10-FIL / F10_F25 ratio

PM25-PRI = PMCON + PM25-FIL

14 PM-CON

PM10-FIL

PM10-PRI

PM25-FIL

PM25-PRI None required; all PM compounds present

15 PM-CON

PM-FIL PM10-FIL = PM-CON / CON_F10 ratio

PM25-FIL = PM10-FIL / F10_F25 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL

16 PM-CON

PM10-PRI

PM25-PRI PM10-FIL = PM10-PRI - PM-CON

PM25-FIL = PM25-PRI - PM-CON

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# Case PM Reported Augmentation Methodology

17 PM-FIL PM10-FIL = PM-FIL * F10_FIL ratio

PM_CON = PM10-FIL * CON_F10 ratio

PM25-FIL = PM10-FIL / F10_F25 ratio

PM10-PRI = PM-CON + PM10-FIL

PM25-PRI = PM-CON + PM25-FIL



# After completing the calculations, the data was QA checked to ensure that t he calculations resulted

in consistent values for the PM complement. On a few occasions, the mix of ratio value and the

pollutants and values provided by the S/L agen cy resulted in negative values when FIL was backcalculated. In this case the ne gative FIL value was set to zero and the PRI value was readjusted. In

a few cases the appropriate combination of ratios, SCC, and control efficiencies were not available

to calculate the PM10-PRI and PM25-PRI values. In these cases, PM10-PRI and PM25-PRI were

set equal.

1.4.4 PM Emission Results

Exhibit 5 compares the original PM emission estimates from the S/L submittals and the 2007

SEMAP emissions estimates calculated using the above methodology. This table is intended to

show that we took what ever States provided in the way of PM and filled in gaps to add in PM-CON

where emissions were missing in order to calculate PM 10 

# -PRI and PM 2.5 

# -PRI for all processes to get

a complete set of particulate data. A spreads heet (PM State SCC Sums .xls) shows the results

obtained from the PM augmentati on process by State and SCC.

Exhibit 5 Comparison of PM Emissions from the In itial S/L Data Submittals and Version 1.1 of

the SEMAP 2007 Point Source Inventory

State Database PM-CON PM10-PRI PM10-FIL PM25-PRI PM25-FIL

AL S/L Data 0 0 57,285 0 29,173

SEMAP 9,511 87,779 78,268 62,878 53,367

FL S/L Data 0 0 26,234 0 0

SEMAP 10,218 36,707 26,489 29,033 18,785

GA S/L Data 0 20,066 0 9,426 0

SEMAP 668 27,359 26,691 19,251 18,858

KY S/L Data 0 24,699 206 2,019 196

SEMAP 325 24,986 24,662 15,435 15,110

MS S/L Data 883 18,871 5,986 11,071 1,739

SEMAP 1,784 18,900 17,116 11,289 9,505

NC S/L Data 18 46,852 28 30,055 16

SEMAP 2,982 46,909 43,926 36,881 33,899

SC 1 

# S/L Data 81 30,602 910 21,488 416

SEMAP 909 31,904 30,995 24,235 23,326

TN 1 

# S/L Data 11,177 26,708 12,826 19,734 7,048

SEMAP 11,270 30,240 18,971 23,742 12,491

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# State Database PM-CON PM10-PRI PM10-FIL PM25-PRI PM25-FIL

VA 2 

# S/L Data 4,783 19,203 14,419 14,888 10,105

SEMAP 4,783 19,203 14,419 14,875 10,092

WV S/L Data 129 6,444 7,507 4,462 3,398

SEMAP 3,904 13,736 9,833 9,173 5,269

1) Includes PM records from EPA’s 2005-based modeling inventory, which have already been

augmented by EPA



# 2) Virginia’s PM augmentation was previously perf ormed using an identical augmentation process

during the development of the 2007 inventor y for the Northeast/Mid-Atlantic States



# 1.5 EMISSION RELEASE POINT QA CHECKS

Stack parameters are an important component of an emission inventory used for regional air quality

modeling. Careful QA was required to ensure that the point source emissions were properly located

both horizontally and vertically on the modeling grid. This section describes the procedures used to

quality assure, augment, and where necessary, re vise, stack parameters using standardized

procedures to identify and correct stack data errors . These procedures were implemented within the

NIF file itself, and are based on the QA procedures built into SMOKE that are designed to catch

missing or out-of-range stack parameters.

1.5.1 QA Checks and Gap-Fill ing for Location Coordinates

The emission release (ER) point record is used to report the location and relev ant physical attributes

of the emission release point. Locat ion coordinates must be reported to identify where emissions are

released to the ambient air, via a stack or non-stack (e.g., fugitive release). If a non-stack, or fugitive

release, coordinates may be reported for the general location of the emission release point. In the

ER record, location data may be reported as x and y coordinates from eit her of two coordinate

systems - Latitude / Longitude (LATLON), or Univer sal TransMercator (UTM). X and Y coordinates

reported as Latitude and Longitude mu st be reported in the decimal degree format specified. X and

Y coordinates reported as UTM Easting and UTM Nort hing, must be reported in kilometers. In order

to comply with the EPA data standard for Latitude/Longitude, any UTM data received in the

SESARM files was processed by the AMEC T eam and converted to, and stored as Latitude

Measure and Longitude Measure in decimal degrees.

All conversions of UTM to LATLON were conducti ng use a spreadsheet developed by the University

of Wisconsin - Green Bay (Dutch 2005). This spr eadsheet tool allowed for batch conversion of UTM

data to decimal degree format and was configured for WGS 84 DATU M. While errors using this

spreadsheet are typically a few meters, rarely 10 or more, the accuracy of the conversion is limited

to the accuracy of the initial UTM data. A degree latitude/longitude is about 111,000 meters. Thus, to

achieve roughly one-meter accuracy you need coordi nates accurate to five decimal places. Four

places will give you 10 meters accuracy and three will give you 100 meter accuracy. Th is accuracy

could not be improved with the originally provi ded UTM coordinates, so all conversions should be

checked for reasonableness.

Once all conversions were made to LATLON dec imal degrees (also the requirement of the SMOKE

emissions processing system), reasonableness checks were conducted on each release point

relative to county centroids and min/max coordi nates associated with the FIPS codes assigned to

each stack. If a stack was found to exist outside of the western-, eastern-, northern- or southernmost boundary of the county (bas ed on SMOKE’s county lat/lon file), the point was flagged for

additional review. These flagged sources were then mapped with GIS software to determine their

placement relative to the FIPS County associated with the stack. If a source was found to be

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# outside of the county boundaries, it was further identified and reported fo r review by the data

provider.

For version 1.10a of the inventor y additional GIS checks were made by personnel from GA EPD to

evaluate any remaining inconsistencies bet ween reported latitude and longitudes and county

boundaries. Corrections were made to several emission release points. The emission release

points corrected are found in Appendix A.

1.5.2 QA Checks and Gap-Filling for Emission Release Parameters

In preparing emissions for grid modeling, valid pa rameters for the physical characteristics of each

release point (stack height, diamet er, temperature, velocity, and flow) are necessary to correctly

place facility release points and a ssociated emissions into vertical layers for proper air quality

modeling. Gaussian dispersion model s need stack parameters to charac terize the plume, which is

needed to estimate proper concentrations from these models. The first step of our quality assurance

involves review of the Emission Release Point Type. Using this type code, we used a routine to

assess the validity of the stack parameters, to repl ace values if necessary, and to fill-in missing data

points. This methodology is vi rtually identical to the EPA met hodology used for the 2002 NEI (EPA

2006a).

We employed a routine that compared each emis sion release point parameter to a minimum and

maximum range of values and when that parameter was missing or was found to exist outside of

that range, we augmented the parameter. We also checked non-fugitive stack parameters for

internal consis tency between:

 stack height and diameter, and

 stack diameter, exit gas velo city, and exit gas flow rate.

When internal consistency was not met, we prov ided replacement values for the parameters.

The following steps summarize the process of finding and replacing missi ng, out-of-range, or

internally inconsistent stack parameters.

Step 1: For fugitive emission release points, replace stack parameters

For fugitive emission release poi nts, we first compared the ex isting height against the following

range thought to be representative of the minimum and maximum values allowable for most fugitive

emission release points.

 Fugitive Release Height: 0.1 to 100 ft

If the height was valid, we kept the height and repl aced all other stack parameters with the defaulted

values listed below. If the height was invalid, we replaced all stack param eters with the defaulted

values.

 Stack Height: 10 ft

 Stack Temperature: 72 o 

# F

 Stack Diameter: 0.003ft

 Stack Velocity: 0.0003 ft/sec

 Stack Flow: 0 cu ft/sec

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# Step 2: For non-fugitive emission release points, find out-of-range or missing stack parameters

For non-fugitive emission release points, we firs t compared existing stack parameters against a set

of the following ranges thought to be representative of the minimu m and maximum values allowable

for most emission release points.

 Stack Height: 0.1 to 1000 ft

 Stack Temperature: 50 to 1,800 o 

# F

 Stack Diameter: 0.1 to 50 ft

 Stack Velocity: 0.1 to 560 ft/sec

 Stack Flow: 0.001 to 1,100,000 ft 3 

# /sec

First we identified missing or out -of range parameters. Then we ev aluated the source category to

determine if out-of-range parameter s were plausible. If any parameter was missing or out-of range,

the parameter was replaced using the procedures de scribed in Step 4. If all parameters were found

to exist within the bounds of the emission re lease point ranges, we proceeded to Step 3.

Step 3: For non-fugitive emission release points, find inconsistencies in stack parameters

We determined any inconsistencies in stack parameters by conducting the following two steps.

A. For stack diameter, we compared the stack diameter to the stack height. For nonfugitive

emission release points, t he stack height may not be less than stack diameter.

B. We determined the internal c onsistency between diameter, veloci ty and flow rate using the

following equation.



# Stack Flow [cu ft/sec] = ( Π [Pi] * (Stack Diameter [ft] / 2) ^ 2) * Stack Velocity [ft/sec]

If the calculated flow and the reported flow are with in 10 % of one another, then internal consistency

was assumed to be valid. If all parameters were f ound to exist within the bounds of the emission

release point ranges in Step 2, and the consisten cy checks (A) and (B) in Step 3 were satisfied, no

additional steps were taken. If any parameter was missi ng or out-of range, or if the parameters failed

the internal consistency tests, the parameter was replaced usin g the procedures described in Step 4.

Step 4: Replace stack parameters for non- fugitive emission release points

The first step in replacing stack parameters was to determine if there are problems with stack height

or diameter. Because stack height and diameter are the physical parameters that are most easily

measured or estimated, when ther e are problems with these parameters, then the entire set of stack

parameters are deemed questionable. If either height or diameter were missing or out-of range, or if

the stack diameter was greater than stack heigh t, then all five parameters were defaulted using

national default sets of physica l parameter data contained in the 2002 NEI Stack Parameter Default

file (EPA 2006b). No additional steps were tak en once all five parameters were defaulted.

If stack height and diameter did not need replacemen t, then velocity and flow rate were evaluated

next. If velocity and flow rate were not internally c onsistent, we conducted QA on the flow rate to

determine if it was reported in cubic feet per minute rather than cubic feet per second as required in

the reporting to EPA.

We corrected flow rates reported in cubic feet per minute to cubic feet per second and then

evaluated the flow rate and velocity for internal c onsistency. If t he internal consistency was not met

for velocity, flow rate, and diameter, Exhibit 6 pr ovides instructions on how we replaced missing, out# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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21 AMEC 

# of-range values, or internally inconsistent valu es for velocity and flow rate based on different

reported scenarios. Velocity and flow rate were augmented either by calcul ation or the use of

national defaults.

Finally, in cases where all five parameters were not defaulted, and velocity and flow rate were

evaluated and replaced if necessary, temperatur e was evaluated. If temperature was missing or

out-of-range, then the temperatur e was defaulted using national default sets of physical parameter

data in the order presented below.

1. SCC match

2. Facility level SIC Code match

3. National default for release points, if no SCC or SIC Code match is possible

Stack parameter QA reports were sent to all data providers. The report contained all of the

emissions release point record s submitted and identifies which parameters were defaulted as a

result of our QA. S/L agencies were asked to revi ew the defaulted records and revise the records if

they do not agree with the defaulted values.

Exhibit 6 - Stack Parameter Data Replacement Matrix (X = Data value present)

Diameter Velocity Flow Rate Action

X X X 1. Check that velocity is within range.

A. If velocity is within range and flow rate does

not meet internal consistency for diameter,

velocity and flow rate, then:

> Calculate flow rate using internal

consistency formula.

B. If velocity is not within range, then:

> Calculate velocity using internal

consistency formula.

> Check that calculated velocity is within

range. If so, then default to calculated

velocity.

> If calculated velocity is not within range,

then default all 5 parameters using national

default set.

X - X 1. Calculate velocity using internal consistency

formula.

2. Check that calculated velocity is within range.

A. If calculated velocity is not within range, then:

> Default all 5 parameters using national

default sets.

X X - 1. Check that velocity is within range.

A. If velocity is within range, then:

> Calculate flow rate using internal

consistency formula.

B. If velocity is not within range, then:

> Default all 5 parameters using national

default sets.

X - - 1. Default velocity using national default sets.

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# Diameter Velocity Flow Rate Action

2. Calculate flow rate using internal consistency

formula.

- X X 1. Default all 5 parameters using national default

sets.



# 1.6 STATE REVIEW OF INITIAL VERSION

This section describes changes made to the 20 07 SEMAP point source inventory based on S/L

agency review and comment. The following changes were incorporated to create Version 1.3 of the

point source inventory.

1.6.1 Alabama

A large increase in VOC and PM emissions from 2002 to 2007 was identified during the review of

Alabama’s initial submittal. Alabama investigated this problem and identified a serious problem in

their data conversion process. Ne w EM and CE tables were provided in May 2010 to correct this

problem. The new submittals we re subjected to the same QA and PM augmentation processes

described in previous sections.

Alabama reviewed the geographic c oordinates for the 34 stacks that were fl agged as being outside

of the appropriate county boundaries. No changes were needed – the sources were either located

off-shore (outside the county boundary) or ve ry close to the edge of the county boundary.

In response to the QA checks of stack paramet ers, Alabama changed the em ission release type to

“01” (fugitive sources) for 98 and accepted the defaul t fugitive emission releas e characteristics. For

another 71 stacks, Alabama changed t he emission release type to “02” (vertical release sources)

and provided corrected stack parameters. Alabama also provided corrections for a number of

additional stacks, either by accepting the re commended defaults or providing corrected data.

1.6.2 Alabama – Jefferson County

Stack parameter changes were made for fugitive emission release points that were recommended

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

1.6.3 Florida

Stack parameter changes were made for fugitive emission release points that were recommended

for change based on the QA c hecks and gap filling process described in Section 1.5.2 of this report.

Florida updated the CAMD-to-NIF crosswalk table to link the CAMD and NIF identifiers. Florida

updated cases where:

 the facility/emission unit may likely have been reported as a di fferent facility (two CAMD

ORIS facilities were combined in Florida’s NIF SI table);

 the EU did not operate in 2007, which is why it was not included in Florida’s NIF database; or

 typographical errors caused a mi smatch between CAMD and NIF.

AMEC made the above updates and now all CAMD units have a match in Florida’s NIF database.

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# 1.6.4 Georgia

Georgia specified that 2008 emissions data should be backcasted to 2007 or and 2005 emissions

data should be projected to 2007. The backcasting of 20 08 emissions and projecting of 2005

emissions was performed in the following manner:

 Facilities with 2007 emi ssions do not get changed;

 For facilities with 2005 and 2008 emissions (but no 2007 emissions), 2007 emissions were

estimated based on a linear interp olation between facility level 2005 and 2008 emissions on

a pollutant-by-pollutant basis to calculate fac ility level 2007 emissions. A scaling factor was

then calculated as the ratio of reported 2008 emissions to interpolated 2007 emissions,

which was used to create to scale back 2008 reported emissions to 2007 at the emission

process level.

 For facilities with only 2008 data (no 2007 or 2005 data available), we used the SIC growth

factors from the VISTAS Best&Final inventory to backcast 2008 reported emissions to 2007.

The VISTAS SIC growth factors were used to calculate a scaling factor which was used to

scale back 2008 reported emissions to 2007 at the emission process level.

 For facilities with only 2005 data (no 2007 or 2008 data available), we used the SIC growth

factors from the VISTAS Best&Final inventory to project 2005 reported emissions to 2007.

The VISTAS SIC growth factors were used to calculate a scaling factor which was used to

project 2005 reported emissions to 2007 at the emission process level.

After the above backcasting and projecting was perfo rmed, additional adjustments were made for

facilities where only 2005 data we re available and the facility di d not operate in 2007 or operated for

only part of 2007. Facilities that did not operate in 2007 were remo ved from the NIF files. For

facilities that operated for part of 2007, the 2005 em issions were approximated for 2007 by multiply

the 2005 emissions by a scaling fa ctor of the number of days the facility operated in 2007 divided

365 days of full year operation. Also, the end date in the NIF EM and PE tables were changed to

reflect the actual date that the facility ceased operati on. These facilities were:

FIPS PLANTID FACILITY NAME DATE

SHUTDOWN SCALING

FACTOR

13159 15900011 Georgia-Pacific Corp Panelboard 15-Aug-07 0.62

13045 04500008 Southwire Co, Copper Division 7-Mar-07 0.18

13121 12100364 Ford Motor Co Atlanta Assembly 1-Dec-07 0.92

13121 12100004 General Shale Brick 28-Mar-07 0.24

13175 17500047 Victor Forstmann, Inc. 1-Apr-07 0.25

13081 08100019 Lasco Bathware 6-Nov-07 0.85

13089 08900031 Siemens Energy & Auto 1-Sep-06 0.00

13241 24100001 Rabun Apparel, Inc. Not operated in

2007 0.00

13261 26100005 Textron Automotive Company 1-Feb-07 0.08



# The following facilities reported emissions data to CAMD but were not in Georgia’s NIF submittal:

FIPSST FIPSCNTY PLANTID ORISID FACILITY NAME

13 147 14700021 70454 HARTWELL ENERGY FACILITY

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# FIPSST FIPSCNTY PLANTID ORISID FACILITY NAME

13 149 14900004 55061 TENASKA GEORGIA

13 149 14900005 55141 HEARD COUNTY POWER LLC

13 149 14900006 7917 CHATTAHOOCHEE ENERGY FACILITY

13 149 14900007 7946 WANSLEY

13 153 15300040 7348 GEORGIA POWER COMPANY, ROBINS CT

13 153 15300042 55040 MID GEORGIA COGEN

13 157 15700034 7765 GEORGIA POWER COMPANY, DAHLBERG

13 205 20500043 7768 SOWEGA POWER LLC

13 205 20500044 55304 BACONTON POWER

13 207 20700030 7829 SMARR ENERGY CENTER

13 233 23300042 7813 SEWELL CREEK ENERGY

13 263 26300013 7916 TALBOT COUNTY ENERGY

13 293 29300027 55267 WEST GEORGIA GENERATING CO

13 297 29700040 7764 MPC GENERATING

13 297 29700041 55244 DOYLE GENERATING FACILITY

13 297 29700042 55128 WALTON COUNTY POWER LLC

13 303 30300039 55332 WASHINGTON COUNTY

13 303 30300040 55672 DUKE ENERGY SANDERSVILLE LLC



# AMEC added these facilities and thei r associated emission units to the NIF tables. All of the units

are gas-fired turbines. AMEC calculated 2007 em issions for these units in the following manner:

 

# NO

x 

# – used the CAMD reported 2007 annual 

# NO

x 

# emissions

 

# SO

2 

# – used the CAMD reported 2007 annual 

# SO

2 

# emissions

 CO – calculated annual CO emissions usi ng the CAMD reported 2007 annual heat input

(mmBtu/year) and the AP-42 emission factor of 0.03 lbs/mmBtu

 PM10-PRI – calculated annual PM10-PRI emissi ons using the CAMD reported 2007 annual

heat input (mmBtu/year) and the AP-42 emission factor of 0.0066 lbs/mmBtu

 PM25-PRI – calculated annual PM25-PRI emissi ons using the CAMD reported 2007 annual

heat input (mmBtu/year) and the AP-42 emission factor of 0.0066 lbs/mmBtu

 VOC – calculated annual VOC emissions usi ng the CAMD reported 2007 annual heat input

(mmBtu/year) and the AP-42 emission factor of 0.0021 lbs/mmBtu

These calculations were revi ewed and approved by Georgia.

Stack parameter changes were made for fugitive emission release points that were recommended

for change based on the QA c hecks and gap filling process described in Section 1.5.2 of this report.

1.6.5 Kentucky

Kentucky compared facility-level emissions in th eir State database to the emissions in the 2007

SEMAP inventory. They identified discrepancies at two facilities: (1) NRE Acquisition Co LLC

(211450019), which appeared to be undercounted by 25.4955 tons of 

# NO

x 

# in the draft 2007 SEMAP

inventory and (2) Chesapeake Applachia LLC (211 9500252), which appeared to be undercounted by

about 76.7157 tons VOC and 6.7362 tons of CO in the SEMAP inventory. These discrepancies

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# were identified and resolved, so that now the Kentucky database and the SEMAP 2007 are in

agreement.

Kentucky provided updated latitude and longitude dat a for 677 stacks that were identified as being

located outside of the count y boundaries. Stack parameter changes for the stack diameter, flow rate,

and velocity were made for fugitive emission release points that were recommended for change

based on the QA checks and gap filling process described in Section 1.5.2 of this report. We

retained Kentucky’s values for stac k height and exit gas temperature.

1.6.6 Kentucky – Jefferson County

Jefferson County updated the coordi nates of emission release point s for large and medium-sized

point sources. Large sources are those with Ti tle V operating permits. Medium-sized sources are

those with synthetic minor operatin g permits. Most of these emi ssion release points will match those

reported in the 2007 National Emissions Inventory (NEI ). Many of these coordinates were digitized

using a geographic information system (GIS) in early April 2010. Others (those showing fewer

significant digits in the UTM coor dinates) were obtained by other m eans, usually by interpolation on

USGS 1:24 000 scale paper maps. Generally the ones that were corrected were those that were

found to be the most inaccurate as seen in the GIS. The 2007 SEMAP inventory was updated with

this new location information.

1.6.7 Mississippi

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities

from EPA’s 2005 NEI that were not included in Mississ ippi’s 2007 submittal. Mississippi reviewed

the facilities that were added and i ndicated that much of the data for the 2005 NEI facilities was for

very small sources, contained dated emissions data, had some double-c ounting of sources,

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably

represent emissions in 2007. As a result, Mississi ppi decided to remove most of the facilities added

from the 2005 NEI from the 2007 SEMAP inventory. The emissions from these sources will be

accounted for in the inventories for area and nonroad sectors.

Mississippi provided updated latitude and longitude dat a for 15 stacks that were identified as being

located outside of the county boundaries.

Mississippi approved the stack parameter chan ges for the stacks that were recommended for

change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

Most of these changes affected fugi tive emission sources with a emission release point of “9999”.

These stacks were updated to c hange the emission release type to “01 – fugitive” and to use the

default fugitive emission release stack parameters described in Section 1.5.2.

Mississippi reviewed the CAMD-to-NIF crosswalk and updated several linkages to correctly map

CAMD identifiers to NIF. Three facilities (B TEC New Albany ORIS 13213, Natchez ORIS 2052, and

AP Holdings Southhaven ORIS 55219) are current ly shut down and did not operate in 2007.

Choctaw Gas generation (ORIS 55634), and RRI Energy (ORIS 55706), are newer and were not

completely represented in Mississi ppi’s original submittal. Missi ssippi provided the necessary stack

data for modeling for both of these facilities.

1.6.8 North Carolina

A large increase in VOC emissions from 2002 to 2007 was identified during the review of North

Carolina’s initial submittal. North Carolina invest igated this problem and ident ified a serious problem

in their data conversion process. A new spreadsheet table was provided in May 2010 to correct this

problem. AMEC converted the spreadsheet file a NIF database. The new submittals were

subjected to the same QA and PM augmentation processes descr ibed in previous sections.

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# North Carolina reviewed the geographic coordinate s for the stacks that were flagged as being

outside of the appropriate count y boundaries. The new submittal mentioned in the previous

paragraph contained corrections to t he flagged latitude and longitude issues.

NC has reviewed the recommended stack replacement parameters and agreed to accept all of the

recommendations based on the SCC code.

In addition, Duke Energy provided additional corr ections for stack parameters for 2007. For the

Marshall Steam Plant, new FGD stacks were install ed in May 2007 (combined stack for Units 1&2),

March 2007 (Unit 3) and May 2006 (Unit 4). For ot her plants (Belews Creek, Cliffside, and G.G.

Allen), new stacks will beco me operational after 2007.

1.6.9 North Carolina – Buncombe County

Buncombe County approved the sta ck parameter changes for the st acks that were recommended

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

In a few cases, Buncombe County updated the orig inal stack parameters for certain stacks and

requested that the updat ed stack data be used.

The geographic coordinates were inadve rtently truncated (not rounded) to 1/100 th 

# of a degree during

the compilation of the initial SEMAP inventory. This problem was corrected in Version 1.3.

Buncombe County compared a sampling of the 2007 SEM AP inventory to what they had submitted

and found them to be in agreement.

1.6.10 North Carolina – Forsyth County

Forsyth County reviewed the data in the SEMAP 2007 inventory and emissions data for the more

significant processes, i.e. the hi ghest emitting sources. The emissi ons for all pollutants except PM

for the processes they reviewed matched their data. The PM emissions did not match the data they

provided data in a few cases. The reason for this difference is due to correc ting inconsistencies in

the reported PM data during t he PM augmentation process. Fo r example, the Corn Products

International facility (ID 3706700732, emission poi nt ES062C, process ID 62C-W had reported PMCON emissions of 11.58 tons but PM10-PRI emissi ons of only 3.41 tons. Since PM-CON cannot be

greater than PM10-PRI, the PM10-PRI value was r eplaced during the PM augm entation process.

Forsyth County provided the missi on facility name (Wake Forest University) for Facility ID

3706700003.

The geographic coordi nates were incorrect for many facilitie s. These have been replaced for all

facilities in Forsyth County.

1.6.11 North Carolina – Mecklenburg County

Mecklenburg County approved the sta ck parameter changes for the st acks that were recommended

for change based on the QA c hecks and gap filling process described in Section 1.5.2 of this report.

1.6.12 South Carolina

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities

from EPA’s 2005 NEI that were not included in S outh Carolina’s 2007 submittal. South Carolina

reviewed the facilities that were added and indicated that much of t he data for the 2005 NEI facilities

was for very small sources, contained dated emissi ons data, had some doubl e-counting of sources,

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably

represent emissions in 2007. As a result, South Carolina decided to remove many of the facilities

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27 AMEC 

# added from the 2005 NEI from the 2007 SEMAP invent ory because they were either minor sources,

out of business, or airports. The emissions from these sources will be accounted for in the

inventories for area and nonroad sectors.

South Carolina provided updated latitude and longit ude data for 14 stacks that were identified as

being located outside of the county boundaries. Five of these stacks were a ssociated with facilities

from the 2005 NEI which were removed from the SEM AP inventory. For the remaining stacks that

were flagged, the facility level lati tude and longitude were used to more accurately loca te the stack.

South Carolina approved the stack parameter ch anges for the stacks that were recommended for

change based on the QA checks and gap filling process described in Sect ion 1.5.2 of this report. In

several cases, South Carolina updated the orig inal stack parameters for certain stacks and

requested that the updat ed stack data be used.

South Carolina reviewed the PM augmentation of PM10-PRI and PM 2.5 

# -PRI and generally agreed

with the small increases in the PM10-PRI and PM 2.5 

# -PRI emissions resulti ng from the augmentation

process. South Carolina expressed a concern a bout the increases that we re made to the certain

fuel burning SCCs (20100101, 20100201, and 20200201). The reason for the small PM10-PRI and

PM25-PRI increase for these SCCs was that a fe w facilities had reported PM10-FIL and PM25-FIL,

not PM10-PRI and PM25-PRI. Since the PM10-FIL and PM25-FIL were repor ted, the augmentation

process calculated a PM-CON value and added it to the PM10-FIL and PM25-FIL values to get the

revised PM10-PRI and PM25-PRI values.

South Carolina reviewed the CAMD-to-NIF crosswal k and updated several linkages to correctly map

CAMD identifiers to NIF. South Carolina also compared the CAMD-reported 

# NO

x 

# and 

# SO

2 

# emissions to the NIF-reported emissions, and updated the NIF emissi ons for several coal-fired

plants with the CAMD emissions after cons ulting with the affected facilities.

1.6.13 Tennessee

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities

from EPA’s 2005 NEI that were not included in T ennessee’s 2007 submittal. Tennessee reviewed

the facilities that were added and i ndicated that much of the data for the 2005 NEI facilities was for

very small sources, contained dated emissions data, had some double-c ounting of sources,

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably

represent emissions in 2007. As a result, Tennessee decided to remo ve most of the facilities added

from the 2005 NEI from the 2007 SEMAP inventory. The emissions from these sources will be

accounted for in the inventories for area and nonroad sectors.

Tennessee provided updated 2007 emissi ons data for 16 facilities that were not in their original

submittal:

FIPS Facility

Identifier Facility Name

47149 0155 NISSAN NORTH AMERICA, INC.

47027 0022 HONEST ABE LOG HOMES, INC., ETC.

47029 0020 SONOCO PRODUCTS COMPANY

47031 0010 ARNOLD ENGINEERING DEVELOPMENT CENTER

47031 0067 BATESVILLE MANUFACTURING, INC.

47031 0113 M-TEK, INC.

47031 0123 CREATEC CORPORATION

47047 0080 STABILT AMERICA, INC

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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28 AMEC 

# FIPS Facility

Identifier Facility Name

47053 0119 Kongsberg Automotive

47071 0074 PRAXIS INDUSTRIES

47077 0060 VOLVO PENTA MARINE PRODUCTS, L.C.

47113 0020 ARMSTRONG HARDWOOD FLOORING

47125 0092 NYRSTAR CLARKSVILLE, INC

47151 0002 HARTCO FLOORING COMPANY

47151 0051 ARMSTRONG HARDWOOD FLOORING

47167 0079 QW MEMPHIS CORPORAT ION - COVINGTON DIVISION



# Tennessee provided updated latitude and longitude data for 25 stacks that were identified as being

located outside of the county bo undaries. Tennessee also provided changes to the stack

parameters for 29 stacks. Stack par ameter changes were made for fugitive emission release points

that were recommended for c hange based on the QA c hecks and gap filling process described in

Section 1.5.2 of this report.

1.6.14 Tennessee – Davidson County

Davidson County reviewed the dra ft point source emission invent ory and approved the emissions

contained in it.

Davidson County approved the stack parameter changes for 723 stacks that were recommended for

change based on the QA checks and gap filling process described in Sect ion 1.5.2 of this report. In

several cases, Davidson County provided up dated stack parameters for selected stacks.

1.6.15 Tennessee – Hamilton County

Stack parameter changes were made for fugitive emission release points that were recommended

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

Hamilton County provided up dated stack latitude and longitude for th ree facilities that were identified

as being located outside of the county boundaries.

1.6.16 Tennessee – Knox County

Stack parameter changes were made for fugitive emission release points that were recommended

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

Knox County provided updat ed stack latitude and longitude for one facility that was identified as

being located outside of the county boundaries.

1.6.17 Tennessee – Shelby County

Shelby County approved the stack parameter ch anges for 765 stacks that were recommended for

change based on the QA checks and gap filling process described in Sect ion 1.5.2 of this report. In

a few cases, Shelby County provided updat ed stack parameters for selected stacks.

Hamilton County provided updated stack latitude and longitude for fa cilities that were flagged as

being located outside of the county boundaries.

1.6.18 Virginia

Virginia provided updated latitude and longitude dat a for 115 stacks that we re identified as being

located outside of the county boundaries.

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# Virginia approved the stack parameter changes for 540 stacks that were recommended for change

based on the QA checks and gap filli ng process described in Section 1.5.2 of this report. The only

exception was for the Jewel Coke Company (ID 51027-00004, stacks 1 an d 3), where Virginia

requested that the original stack exhaust gas tem peratures of 1500 degrees Fahrenheit be retained.

As part of the development of a 2007 inventory for the Mid-Atlantic and Nort heast States directed by

MARAMA, Virginia developed and approved the 2007 CAMD-to-NIF crosswalk and the 2007

emission values for all sources.

1.6.19 West Virginia

West Virginia approved the stack parameter ch anges for 540 stacks that were recommended for

change based on the QA checks and gap filling process described in Section 1.5.2 of this report.

There were four exceptions (Aker Plastics 5400300026, Gr atech International 5403300001,

Monongahela Power Harrison 5403300015, DuPont Belle 5403900001) where West Virginia

requested that the original stack par ameters for certain stacks be retained.

West Virginia reviewed the locations for the se ven facilities flagged as be ing outside of the county

boundaries and provided updated stack latit ude and longitude for t hese facilities.

West Virginia reviewed the draft emission inventory and confirmed that all poi nt source facilities are

represented in the inventor y, that the PM augmentat ion procedure produced reasonable results, and

the 2007 emissions in the SEMAP inventory agreed with the data they submitted.

West Virginia reviewed the CAMD-to-NIF crossw alk and identified the linkage between CAMD and

NIF identifiers for the Union Carb ide Corporation (5403900003) boile rs B25, B26, and B27. West

Virginia approved all other linkages between CAMD and NIF identifiers.

1.7 STAKEHOLDER REVIEW

S/L agencies provided access to Version 1.3 of t he 2007 point source inventory and solicited input

from various stakeholders including EPA, the regulated community, academia, environmental

groups, and the general public. This section documents the changes made to Version 1.3 based on

S/L agency review of stakeholder comments as well as any additi onal updates or corrections

identified by the S/L agencies.

1.7.1 Alabama

The National Lime Association requ ested consideration of a modification to PM emissions data for

one of their facilities in Alabam a (Unimin Lime Corporation, Ca lera Plant). The request was

reviewed by State staff and the suggest ed correction was justified and made.

1.7.2 Florida

Lakeland Electric requested that the 

# SO

2 

# and 

# NO

x 

# emission values from the EPA CAMD submittal

be used instead of the values repo rted to the State. The CAMD represent the emissions more

accurately that the State submittal for two plant s (Plant IDs 1050004 and 1050003). Florida agreed

to make these changes.

Tampa Electric reviewed the dat abase and suggested several corrections . Most of the changes are

due to the installation and operation of the SCR control devices on Big B end units 1-4. Tampa

Electric also evaluated filterabl e and condensable PM emissions for a ll of its major generating units

and provided better, unit specific, emission rates fo r these units where ava ilable. Finally, Tampa

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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30 AMEC 

# Electric provided some corrections to stack exhaust gas parameters. Florida agreed to make all of

these changes.

Southern Company indicated that the inventory stack data for Cris t plant reflects the current

scrubbed stack parameters, not the operating paramete rs in 2007. Appropriate stack parameters for

2007 were submitted and review ed/approved by Florida.

1.7.3 Georgia

Georgia reviewed the emissions va lues and stack parameters for the Georgia Power facilities in the

State. Georgia provided updated PM and 

# NH 3 

# emissions data for all Georgia Power facilities. The

revised PM emission values included condensable emissions which were previously missing from

the inventory. Georgia also provided updated st ack parameters for selected Georgia Power stacks.

Georgia also identified a number of emission units where the PM 2.5 

# emissions were greater than the

PM10 emissions. The source of this error was in vestigated and ident ified, and revisions were made

to correct this error.

1.7.4 Kentucky

Kentucky identified that t he PM point source emissions originally submitted for all Kentucky counties,

excluding Jefferson County, should be c onsidered as filterable PM emissi ons. The original submittal

contained pollutant codes (PM-PRI, PM10-PRI, PM25-PRI) that represent the sum of filterable and

condensable emissions. These should have been reported as filterable only (PM-FIL, PM10-FIL,

PM25-FIL). AMEC changed the pollu tant codes to represent filt erable emissions only, and re-ran

the PM augmentation process described previously in Section 1.4 to add condensable emissions to

the filterable emissions. Kentucky reviewed and approved the revised PM emissions, except for a

few EGUs. Kentucky worked wi th these utilities in obtaining updated PM emissi ons data that

included both filterable and condens able emissions. These changes to the EGU PM emissions are

discussed further in Section 1.9.

1.7.5 North Carolina

Duke Energy indicated that the SCC for Marshall Units 1&2 were 10200202 and 10200502

(industrial boiler, coal and oil) but should be 10100202 and 10100502 (electric generation boiler,

coal and oil). Duke Energy requ ested that the SCC be changed as that will impact how boilers are

grouped by category for various regulator y and emission projection scenarios.

1.7.6 Tennessee

Tennessee identified three facilities (APAC-TN Harrison Construction Division, Dyersburg

Compressor Station, Kimberly Clark Corporation) that had duplicate ent ries in the emission

inventory. AMEC investigated this issue and identified the erro r. The duplicate entries were

removed.

Tennessee also provided updated 2007 emissions data for the CalsonicKans ei North America -

Lewisburg Operations facility.

1.8 IDENTIFICATION OF EGU AND NONEGU POINT SOURCES

States were asked to classify units in the 2007 SEMAP emissions inventory as either EGU or

nonEGU for emission projection purposes. Emissi on projections for EGU point sources are being

developed by the Eastern Regional Technical Adviso ry Committee (ERTAC). The emissions from

point sources classified as nonEGUs will be projec ted using the methods and data developed by

SEMAP.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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31 AMEC 

# Most, but not all, of the units t hat are required to repor t hourly emissions to EPA’s Clean Air Markets

Division (CAMD) are considered to be EGUs. CAMD implements EPA’s rule found in Volume 40

Part 75 of the Code of Federal Regulations (CFR), which requires an hourly accounting of emissions

from each affected unit - i.e., sources participat ing in an emissions cap and trade program under the

Acid Rain Control Program, the 

# NO

x 

# Budget Trading Program, or the Clean Air Interstate Rule. The

following guidance was provided to States to determi ne whether a unit that reports to CAMD should

be classified as an EGU or nonEGU:

For the ERTAC process, a unit should only be cons idered EGU if it meets the following criteria:

 An EGU sells most of the power generated to the electrical grid;

 An EGU burns mostly commercial fuel. Commercia l fuel in this case means natural gas, oil,

and coal. Wood would not be c onsidered as commercial fuel because some states have

them as renewable, therefore, to prevent double counting, unl ess it's already in the CAMD

database, units that burn wood and other renewable sources (depending on each state's

own definition) should not be considered as EGU.

The following units were NOT considered as EGU for the purpose of projection emissions:

 A unit that generates power for a fac ility but occasionally sells to the grid;

 Emergency generators;

 Distributed generation units.

S/L agencies were provided with a list of units that report to CAMD as well as a list of units with an

electric generating unit SCC (1-01-xx x-xx or 2-01-xxx-xx). From t hese lists, S/L agencies identified

units that should be classified as EGUs and thos e that should be classified as nonEGUs. A few

States also identified units with SCCs beginning with 1-01 or 2-01 that do not report to CAMD but

which should be classified as EGUs; however, for em ission projection purposes these units will be

processed using the nonEGU projection methodology developed by SEMAP.

AMEC added a flag to the NIF EP table to identify each unit according to the following classification

scheme:

 EGU-CAMD are combustion units that report hour ly emissions to the CAMD database and

have been classified as EGUs by the S/L agency;

 EGU-nonCAMD are combustion units with SCC star ting with 101 or 201 that are not

contained in CAMD database;

 nonEGU-CAMD are combustion units that report hour ly emissions to the CAMD database

and have been classified as nonE GUs by the S/L agency; and

 nonEGU-nonCAMD are all other point sources not classified above.

The above flags allow for sources to be categoriz ed in different ways for emission projection and

emission reporting purposes.

1.9 FINAL S/L AGENCY QA REVIEW

Two final QA checks were made. The first check was for S/L agenc ies to verify the PM emissions

data for coal- and oil-fired units included PM co ndensable emissions in addition to PM filterable

emissions. The second check was for S/L agencies to verify the location and emission values for

certain sources via review of emission bubble pl ots prepared by another SEMAP contractor. This

section documents the changes m ade based on these final QA checks. In addition, the

documentation was revised to address comments provided by EPA Region 4.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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32 AMEC 

# 1.9.1 Kentucky

Kentucky coordinated the review of PM emissions with utilities in the Commonwealth and provided

updated PM condensable emissions for the following units:

 Duke Energy East Bend (21-015-00029) Unit 2;

 TVA Shawnee (21-145-00006) Units 1 through 10;

 TVA Paradise (21-177-00006) Units 1, 2, and 3; and

 Kentucky Energy Reid/Henderson (21-233-00001) Units H1 and H2

1.9.2 North Carolina

Both Duke Energy and Progress Energy subm itted information to confirm that the PM 2.5 

# -PRI and

PM10-PRI emission estimates fo r its facilities do include both filterable and condensable values.

1.9.3 North Carolina – Forsyth County

In its original submittal, Forsyth County subm itted a mix of 2007 and 20 08 emission data. After

further reviewing the 2007 and 2008 data, Forsyth County identified several revisions to make the

data more representative of 2007. One facility (VP Buildings, Inc., Pl ant ID 00488) that shut down in

2008 was omitted for the initial submittal and was added to the SEMAP 2007 inventory. The only

other significant change was the add ition of the coal boilers at R.J. Reynolds Tobacco Company

(Plant ID 00039) to the SEMAP 2007 inventory t hat were shut down in 2008. Some additional

relatively minor corrections were made as well.

1.9.4 South Carolina

South Carolina confirmed that the PM condensable emi ssions are included in the PM10-PRI and

PM 2.5 

# -PRI data provided for coal- and oil-fired EGUs.

1.9.5 Virginia

Virginia confirmed that t he PM condensable emissions ar e included in the PM10-PRI and PM 2.5 

# -PRI

data provided for coal- and oil-fired EGUs.

1.9.6 West Virginia

After reviewing the emission density maps and em ission bubble plots, West Virginia submitted

revisions to the geographic coor dinates at three facilities ( 54-009-00012 Impress USA, 54-021-

00001 Columbia Gas Glenville, 54-0 57-00008 Newpage Corporation).

1.9.7 Changes for Version 1.9 of the Point Source Inventory

The information presented above relates to Version 1. 8 of the point source in ventory. This section

documents the changes to Version 1.8 of the SEMAP point source emission inventory to create

Version 1.9. The purpose of these revisions were to resolve signi ficant differences in emissions as

reported by States in Version 1. 8 and the emissions as reported in the Clean Air Market Division’s

hourly emission database. Each change that was made is identif ied along with the CAMD and

SEMAP unit identifiers:

 CAMD_ID = Plant ORIS / Boiler ID

 SEMAP_ID = FIPS county code / PlantID / PointID / ProcessID

Several States have indicated that they would like to the SEMAP inventory to be updated to reflect

the CAMD 

# NO

x 

# and 

# SO

2 

# emissions. These changes have not yet been made pending the resolution

of the potential adjustments to the CAMD emissions to account for overly conservative missing data

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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33 AMEC 

# substitution procedures spec ified by EPA. Once States review the proposed revisions to the CAMD

emissions to account for missing data substitution, St ates will be given the oppor tunity to specify the



# NO

x 

# and 

# SO

2 

# emissions to be used in the final SEMAP 2007 inventory. The choices are: 1) retain

State-supplied emissions; 2) use CAMD emissions as provided in standard EPA data sets; or 3) use

CAMD emissions as modified by SEMAP to a ccount for overly conservative missing data

substitution values.

1.9.7.1 Alabama

Alabama Power EC Gaston (CAMD_ID = 26 / 1; SEMAP_ID = 01117 / 0005 / 002 / 01)

SEMAP 

# NO

x 

# changed from 1,292 tons to 3,271.6 tons to match CAMD emissions

Alabama Power Gorgas (CAMD_ID = 8 / 10; SEMAP_ID = 01127 / 0001 / 008 /01

SEMAP 

# NO

x 

# changed from 5,117 tons to 5,727.5 tons to match CAMD emissions

PowerSouth Energy Coop (CAMD_ID = 56 / 2; SEMAP_ID = 01129/ 0001/ 003 / 01

SEMAP 

# NO

x 

# changed from 4,559 tons to 3,717 t ons to match CAMD emissions

PowerSouth Energy Coop (CAMD_ID = 56 / 3; SEMAP_ID = 01129/ 0001/ 003 / 01

SEMAP 

# NO

x 

# changed from 4,698 tons to 4,995.5 tons to match CAMD emissions

1.9.7.2 Alabama – Jefferson County

No issues identified.

1.9.7.3 Florida

TECO Big Bend (CAMD_ID = 645 / BB01; SEMAP_ID = 12057 / 0570039 / 1 / 1)

SEMAP 

# NO

x 

# changed from 4,507 tons to 10,044 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1,610 tons to 2,999 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB02; SEMAP_ID = 12057 / 0570039 / 2 / 2)

SEMAP 

# NO

x 

# changed from 3,889 tons to 10,051 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1,389 tons to 2,717 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB03; SEMAP_ID = 12057 / 0570039 / 3 / 3)

SEMAP 

# NO

x 

# changed from 1,571 tons to 3,838 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 2,035 tons to 1,773 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB01; SEMAP_ID = 12057 / 0570039 / 1 / 1)

BoilerID in SEMAP EP Table changed from BB O 4 to BB 0 4 to match CAMD boiler ID

SEMAP 

# NO

x 

# changed from 1,183 tons to 1,192 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 2,305 tons to 2,414 t ons to match CAMD emissions

1.9.7.4 Georgia

No changes reques ted by State.

1.9.7.5 Kentucky

Kentucky provided revised SEMAP-to-CAMD mappi ng for the seven turbines at the KY Utilities

Brown Station (CAMD_ID 1355 / #5 to #11; SEMAP_ID 21167 / 00001 /023-29). The revised

mapping for emission point 023-29 is as follows:

SEMAP

Process ID V_1_8

CAMD Boiler ID Revised V_1_9

CAMD Boiler ID

2 5 5

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34 AMEC 

# SEMAP

Process ID V_1_8

CAMD Boiler ID Revised V_1_9

CAMD Boiler ID

3 5 8

4 6 8

5 6 9

6 7 9

7 7 10

8 8 10

9 8 11

10 9 11

11 9 6

12 10 6

13 10 7

14 11 7



# 1.9.7.6 Kentucky – Jefferson County

No issues identified.

1.9.7.7 Mississippi

No changes reques ted by State.

1.9.7.8 North Carolina

No changes reques ted by State.

1.9.7.9 North Carolina – Buncombe County

No issues identified for Progress Energy – Ashville.

1.9.7.10 North Carolina – Forsyth County

No affected facilities in the county.

1.9.7.11 North Carolina – Mecklenburg County

No affected facilities in the county.

1.9.7.12 South Carolina

SCE&G Urquhart (CAMD_ID = 3295; SEMAP_ID = 45003 / 0080-0011)

There was an incorrect linkage between the ID s for the combustion turbines. The SEMAP

NIF EP table was changed to correctly matc h CTs 4, 5, 6 between the CAMD and SEMAP

inventories

CAMD unit URQ4 is now linked to EU11 (p reviously was linked to EU04 – CT 1)

CAMD unit URQ5 is now linked to EU12 (p reviously was linked to EU05 – CT 2)

CAMD unit URQ6 is now linked to EU13 (p reviously was linked to EU06 – CT 3)

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 3)

SEMAP 

# NO

x 

# changed from 3.9 tons to 0 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.183 tons to 0 t ons to match CAMD emissions

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 4)

SEMAP 

# NO

x 

# changed from 45 tons to 33.6 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.178 tons to 1.42 t ons to match CAMD emissions

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35 AMEC 

# Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 3)

SEMAP 

# NO

x 

# changed from 18.3 tons to 0 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 0.847 tons to 0 t ons to match CAMD emissions

Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 4)

SEMAP 

# NO

x 

# changed from 42.4 tons to 31.31 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.108 tons to 1.05 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT1A; SEMAP_ID = 45007 / 0200-0144 / 001 / 1)

SEMAP 

# NO

x 

# changed from 218.17 tons to 19.71 to ns to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT1B; SEMAP_ID = 45007 / 0200-0144 / 001 / 3)

SEMAP 

# NO

x 

# changed from 218.17 tons to 19.71 to ns to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT2A; SEMAP_ID = 45007 / 0200-0144 / 002 / 1)

SEMAP 

# NO

x 

# changed from 33.40 tons to 16.29 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT2B; SEMAP_ID = 45007 / 0200-0144 / 002 / 3)

SEMAP 

# NO

x 

# changed from 32.40 tons to 18.21 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT3; SEMAP_ID = 45007 / 0200-0144 / 003 / 1)

SEMAP 

# NO

x 

# changed from 0.072 tons to 4.4 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT4; SEMAP_ID = 45007 / 0200-0144 / 003 / 2)

SEMAP 

# NO

x 

# changed from 0.060 tons to 5.13 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT5; SEMAP_ID = 45007 / 0200-0144 / 003 / 3)

SEMAP 

# NO

x 

# changed from 0.078 tons to 4.79 t ons to match CAMD emissions

SCE&G Hagood (CAMD_ID = 3285 / HAG4; SEMAP_ID = 45019 / 0560-0029 / 001 / 2)

SEMAP 

# NO

x 

# changed from 21.1 tons to 31.28 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 34.5 tons to 1.22 t ons to match CAMD emissions

1.9.7.13 Tennessee

U.S. DOE, Y-12 PLANT (CAMD_ID = 880055 / 31&32&34; SEMAP_ID 47001 / 0020 / 002)

CAMD units 31, 32, and 34 had no match in the SEMAP inventory. Tennessee provided the

SEMAP identifiers to provide the correct linkage between CAMD and SEMAP. The NIF EP

table was changed to provide the cross-refe rence between CAMD and SEMAP identifiers.

Bowater Calhoun (CAMD_ID = 50956 / 11& 12; SEMAP_ID = 47107 / 0012 / 015)

CAMD reports two coal-fired boilers #11 and #1 2. In SEMAP, there is only one emission

point -015 – that is a coal fi red boiler. To improve the match between CAMD and SEMAP,

new records were created in the SEMAP databa se to disaggregate em issions from boilers

#11 and #12 into individual records using the 

# NO

x 

# and 

# SO

2 

# emissions data provided by

Tennessee.

TVA Cumberland (CAMD_ID = 3399 / A1; SEMAP_ID = 47161 / 0011 / 003 / 01)

The SEMAP inventory reported 15.3 tons of 

# NO

x 

# for Auxiliary boiler A1 , which was based on

allowable emissions and is conserva tive. For 2007, based on a tested 

# NO

x 

# rate of

0.067lb/mmBtu and fuel usage of 132317 gallons of #2 oil, 

# NO

x 

# emissions for Auxiliary boiler

A1 changed to 0.6 ton.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

36 AMEC 

# TVA Cumberland (CAMD_ID = 3399 / A2; SEMAP_ID = 47161 / 0011 / 004 / 01)

The SEMAP inventory reported 15.3 tons of 

# NO

x 

# for Auxiliary boiler A2, which was based on

allowable emissions and is conservative. Th is unit was not in service in 2007 and does not

show up in CAMD for 2007. It did not bec ome operational until 2008. Boiler A2 was

inadvertently included in the 2007 SEMAP emissi on database submittal. All emissions for

this unit were changed to 0 for the 2007 SEMAP inventory.

1.9.7.14 Tennessee – Davidson County (Nashville)

Eastman Chemical (CAMD_ID = 50481 / 83-23 & 83-24; SEMAP_ID = 47163 / 0003 / 020101)

In the SEMAP V1_8 inventory, the two boilers #23 and #24 were included as a group with

boilers #11-22. To improve the match between CAMD and SEMAP, new records were

created in the SEMAP database to disaggregat e emissions from boilers #23 and #24 into

individual records using the 

# NO

x 

# and 

# SO

2 

# emissions data provided by Tennessee.

Eastman Chemical (CAMD_ID = 50481 / 253-25, 253-26, 253-27, 253-28 and 253-29; SEMAP_ID =

47163 / 0003 / 021520)

In the SEMAP V1_8 inventory, the five boilers #25 to #29 were grouped together as a single

emission point. To improve the match bet ween CAMD and SEMAP, new records were

created in the SEMAP database to disaggregate em issions for each boiler #25 to #29 into

individual records using the 

# NO

x 

# and 

# SO

2 

# emissions data provided by Tennessee.

Eastman Chemical (CAMD_ID = 50481 / 325-30 & 325-31; SEMAP_ID = 47163 / 0003 / 261501)

In the SEMAP V1_8 inventory, the two boile rs #30 and #31 were grouped together as a

single emission point. To improve the match between CAMD and SEMAP, new records

were created in the SEMAP database to dis aggregate emissions for each boiler #30 to #31

into individual records using the 

# NO

x 

# and 

# SO

2 

# emissions data provided by Tennessee.

1.9.7.15 Tennessee – Hamilton County (Chattanooga)

No affected facilities in the county.

1.9.7.16 Tennessee – Knox County (Knoxville)

No affected facilities in the county.

1.9.7.17 Tennessee – Shelby County (Memphis)

No issues identified.

1.9.7.18 Virginia

Virginia provided detailed comments on how to create hourly emissions for each unit in CAMD. No

specific changes were request ed to the SEMAP inventory.

1.9.7.19 West Virginia

No changes reques ted by State.

1.9.8 Changes for Version 1.10a of the Point Source Inventory

This section documents t he changes to Version 1.9 of the SEMAP point source emission inventory

to create Version 1.10a. The purpos e of these revisions were to re solve significant differences in

emissions as reported by States in Version 1.9 and the CEMs emissi ons as reported in the Clean Air

Market Division’s hourly emission database. Each change that was made is i dentified along with the

CAMD and SEMAP unit identifiers:

 CAMD_ID = Plant ORIS / Boiler ID

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

AMEC Project No.: 6066-09-0326.02 January 18, 2012

37 AMEC 

#  SEMAP_ID = FIPS county code / PlantID / PointID / ProcessID

These changes were made because a number of States have indicat ed that they would like to have

the SEMAP inventory updated to reflect the CAMD 

# NO

x 

# and 

# SO

2 

# emissions from CEMS data.

These changes had not been made in version 1.9 because of potent ial adjustments to the CAMD

emissions to account for overly conservative missi ng data substitution proce dures specified by EPA.

Once States were allowed to review the proposed revisions to the CAMD emissions to account for

missing data substitution, they were gi ven the opportunity to specify the 

# NO

x 

# and 

# SO

2 

# emissions to

be used in the final SEMAP 2007 inventory. The c hoices were: 1) retain State-supplied emissions;

2) use CAMD emissions as prov ided in standard EPA data sets; or 3) use CAMD emissions as

modified by SEMAP to account for overly cons ervative missing data substitution values.

In addition to the changes requested for the CEMS data, there were other changes made as a result

of consultation with the States. Those changes are listed separately. Finally, a number of emission

release points were identified as having incorrect la titude/longitude values. T he final portion of this

section details the emission rel ease points that were modified and the new latitude/longitude values.

The information below identifies those facilities t hat had their emissions chang ed as a result of the

CEMS review.Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201238AMEC1.9.8.1 AlabamaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01001 Southern Power Company 0010 001 01 7897 1A NOX 42.631001001 Southern Power Company 0010 001 01 7897 1A SO2 2.058001001 Southern Power Company 0010 002 01 7897 1B NOX 42.855001001 Southern Power Company 0010 002 01 7897 1B SO2 2.084001001 Southern Power Company 0010 003 01 7897 2A NOX 37.757001001 Southern Power Company 0010 003 01 7897 2A SO2 1.530001001 Southern Power Company 0010 004 01 7897 2B NOX 33.353001001 Southern Power Company 0010 004 01 7897 2B SO2 1.472001001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 NOX 14.544001001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 SO2 0.546001001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 NOX 12.697001001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 SO2 0.490001001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 NOX 11.224001001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 SO2 0.467001001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 NOX 15.905001001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 SO2 0.731001001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 NOX 10.436001001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 SO2 0.686001001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 NOX 11.018001001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 SO2 0.567001015 Calhoun Power Company I LLC GeneratingStation 0073 001 01 55409 CT1 NOX 19.525001015 Calhoun Power Company I LLC Generating Station 0073 001 01 55409 CT1 SO2 0.546001015 Calhoun Power Company I LLC GeneratingStation 0073 002 01 55409 CT2 NOX 20.092001015 Calhoun Power Company I LLC Generating Station 0073 002 01 55409 CT2 SO2 0.527001015 Calhoun Power Company I LLC GeneratingStation 0073 003 01 55409 CT3 NOX 22.875001015 Calhoun Power Company I LLC Generating Station 0073 003 01 55409 CT3 SO2 0.600001015 Calhoun Power Company I LLC GeneratingStation 0073 004 01 55409 CT4 NOX 21.961001033 TVA 0010 009 01 47 1 NOX 3,103.485001033 TVA 0010 009 01 47 1 SO2 5,786.830001033 TVA 0010 009 01 47 2 NOX 2,880.063001033 TVA 0010 009 01 47 2 SO2 5,339.807001033 TVA 0010 009 01 47 3 NOX 3,104.7600Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201239AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01033 TVA 0010 009 01 47 3 SO2 5,799.600001033 TVA 0010 009 01 47 4 NOX 2,923.267001033 TVA 0010 009 01 47 4 SO2 5,496.512001039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 NOX 18.536001039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 SO2 0.203001039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 NOX 23.972001039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 SO2 1.196001039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 NOX 20.701001039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 SO2 0.933001055 Alabama Power Company 0002 001 01 7 1 NOX 1,212.747001055 Alabama Power Company 0002 001 01 7 1 SO2 5,556.217001063 Alabama Power Company 0001 001 01 10 1 NOX 2,965.247001063 Alabama Power Company 0001 001 01 10 1 SO2 16,379.736001063 Alabama Power Company 0001 001 01 10 2 NOX 3,148.497001063 Alabama Power Company 0001 001 01 10 2 SO2 14,267.787001063 Alabama Power Company 0001 002 01 10 CT2 NOX 28.133001063 Alabama Power Company 0001 002 01 10 CT2 SO2 0.556001063 Alabama Power Company 0001 003 01 10 CT3 NOX 21.375001063 Alabama Power Company 0001 004 01 10 CT4 NOX 21.493001063 Alabama Power Company 0001 005 01 10 CT5 NOX 20.356001063 Alabama Power Company 0001 006 01 10 CT6 NOX 24.899001063 Alabama Power Company 0001 007 01 10 CT7 NOX 22.287001063 Alabama Power Company 0001 007 01 10 CT7 SO2 0.479001063 Alabama Power Company 0001 008 01 10 CT8 NOX 14.797001063 Alabama Power Company 0001 009 01 10 CT9 NOX 14.095001063 Alabama Power Company 0001 010 01 10 CT10 NOX 16.947001071 TVA 0008 001 01 50 1 NOX 1,654.184001071 TVA 0008 001 01 50 1 SO2 3,549.110001071 TVA 0008 001 01 50 2 NOX 1,696.500001071 TVA 0008 001 01 50 2 SO2 3,670.096001071 TVA 0008 001 01 50 3 NOX 1,759.766001071 TVA 0008 001 01 50 3 SO2 3,757.587001071 TVA 0008 001 01 50 4 NOX 2,038.6580Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201240AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01071 TVA 0008 001 01 50 4 SO2 4,357.298001071 TVA 0008 001 01 50 5 SO2 2,834.696001071 TVA 0008 001 01 50 6 NOX 1,823.314001071 TVA 0008 001 01 50 6 SO2 3,934.988001071 TVA 0008 002 01 50 7 NOX 3,694.200001071 TVA 0008 002 01 50 7 SO2 6,518.666001071 TVA 0008 003 01 50 8 NOX 3,646.963001071 TVA 0008 003 01 50 8 SO2 4,100.945001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 101 1 6002 1 NOX 5,772.419001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011101 1 6002 1 SO2 16,967.289001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 102 1 6002 2 NOX 5,682.308001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011102 1 6002 2 SO2 15,760.193001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 103 1 6002 3 NOX 5,446.441001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011103 1 6002 3 SO2 13,515.093001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 104 1 6002 4 NOX 5,160.873001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011104 1 6002 4 SO2 13,285.274001081 Southern Power Company 0036 001 01 7710 1A NOX 36.006001081 Southern Power Company 0036 001 01 7710 1A SO2 1.846001081 Southern Power Company 0036 002 01 7710 1B NOX 34.501001081 Southern Power Company 0036 002 01 7710 1B SO2 1.822001081 Southern Power Company 0036 003 01 7710 2A NOX 40.466001081 Southern Power Company 0036 003 01 7710 2A SO2 2.116001081 Southern Power Company 0036 004 01 7710 2B NOX 37.216001081 Southern Power Company 0036 004 01 7710 2B SO2 2.116001097 Alabama Power Company 1001 001 01 3 1 NOX 1,484.265001097 Alabama Power Company 1001 001 01 3 1 SO2 4,814.710001097 Alabama Power Company 1001 001 01 3 2 NOX 1,653.985001097 Alabama Power Company 1001 001 01 3 2 SO2 5,244.420001097 Alabama Power Company 1001 001 01 3 3 NOX 2,834.011001097 Alabama Power Company 1001 001 01 3 3 SO2 8,907.217001097 Alabama Power Company 1001 002 01 3 4 NOX 3,000.114001097 Alabama Power Company 1001 002 01 3 4 SO2 10,938.662001097 Alabama Power Company 1001 003 01 3 5 SO2 21,362.0720Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201241AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01097 Alabama Power Company 1001 005 01 3 6A NOX 37.865001097 Alabama Power Company 1001 005 01 3 6A SO2 2.309001097 Alabama Power Company 1001 006 01 3 6B NOX 39.424001097 Alabama Power Company 1001 006 01 3 6B SO2 2.311001097 Alabama Power Company 1001 007 01 3 7A NOX 33.936001097 Alabama Power Company 1001 007 01 3 7A SO2 2.346001097 Alabama Power Company 1001 008 01 3 7B NOX 33.409001097 Alabama Power Company 1001 008 01 3 7B SO2 2.258001097 Alabama Power Company 8073 001 01 7721 CC1 NOX 38.459001097 Alabama Power Company 8073 001 01 7721 CC1 SO2 3.356001097 Mobile Energy LLC 8066 001 01 55241 COG01 NOX 8.669001103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 NOX 38.234001103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 SO2 2.198001103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 NOX 28.891001103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 SO2 1.841001103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 NOX 33.962001103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 SO2 2.081001103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 NOX 45.655001103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 SO2 3.655001103 Morgan Energy Center LLC 0080 002 01 55293 CT-2 SO2 1.648001103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 NOX 28.532001103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 SO2 1.692001103 Solutia Inc 0010 001 01 880041 Z006 NOX 259.408001103 Solutia Inc 0010 002 01 880041 X053 NOX 0.021001103 Solutia Inc 0010 003 01 880041 X015 NOX 458.016001117 Alabama Power Company 0005 001 01 26 1 NOX 3,271.590001117 Alabama Power Company 0005 001 01 26 1 SO2 20,341.725001117 Alabama Power Company 0005 001 01 26 2 NOX 3,397.051001117 Alabama Power Company 0005 001 01 26 2 SO2 20,957.713001117 Alabama Power Company 0005 002 01 26 4 NOX 3,098.079001117 Alabama Power Company 0005 002 01 26 4 SO2 17,818.254001117 Alabama Power Company 0005 003 01 26 5 NOX 8,138.996001117 Alabama Power Company 0005 003 01 26 5 SO2 64,663.2850Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201242AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01127 Alabama Power Company 0001 003 01 8 7 NOX 1,445.365001127 Alabama Power Company 0001 003 01 8 7 SO2 8,930.936001127 Alabama Power Company 0001 004 01 8 9 SO2 10,310.752001129 Alabama Power Company 0018 001 01 7697 CC1 NOX 247.086001129 Alabama Power Company 0018 001 01 7697 CC1 SO2 2.561001129 PowerSouth Energy Cooperative Inc 0001 001 02 56 1 NOX 715.381501129 PowerSouth Energy CooperativeInc 0001 001 02 56 1 SO2 1,836.045501129 PowerSouth Energy Cooperative Inc 0001 002 01 56 1 NOX 715.381501129 PowerSouth Energy CooperativeInc 0001 002 01 56 1 SO2 1,836.045501129 PowerSouth Energy CooperativeInc 0001 002 01 56 2 NOX 3,703.715001129 PowerSouth Energy CooperativeInc 0001 002 01 56 2 SO2 4,845.338001129 PowerSouth Energy CooperativeInc 0001 003 01 56 3 NOX 4,995.522001129 PowerSouth Energy CooperativeInc 0001 003 01 56 3 SO2 7,735.500001129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 NOX 2.985001129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 SO2 0.040001129 PowerSouth Energy Cooperative Inc 0012 003 01 7063 **3 SO2 0.02401.9.8.2 Alabama – Jefferson CountyNo issues identified.1.9.8.3 FloridaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12001 CITY OF GAINESVILLE, GRU 0010006 3 1 663 B1 NOX 201.596112001 CITY OF GAINESVILLE, GRU0010006 3 1 663B1 SO2 0.608812001 CITY OF GAINESVILLE, GRU 0010006 3 2 663 B1NOX 40.077912001 CITY OF GAINESVILLE, GRU 0010006 3 2 663 B1 SO2 110.693212001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 NOX 3,624.850012001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 SO2 7,837.084012001 CITY OF GAINESVILLE, GRU0010006 6 1 663CT3 NOX 9.199012001 CITY OF GAINESVILLE, GRU0010006 6 1 663CT3 SO2 0.166012001 FLORIDA POWER CORPORATION D/B/A PROGRESS 0010001 7 2 7345 1 NOX 109.743012001 FLORIDA POWER CORPORATION D/B/A PROGRESS 0010001 7 2 7345 1 SO2 1.020012001 GAINESVILLE REGIONAL UTILITIES0010005 101 664 CC1 NOX 30.159012001 GAINESVILLE REGIONAL UTILITIES0010005 10 1 664CC1 SO2 0.6710Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201243AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 NOX 2.932512005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 SO2 6.758512005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 NOX 2.052912005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 SO2 6.093212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 NOX 2,768.137012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 SO2 6,379.594212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 NOX 2,967.463212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 SO2 8,807.783012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 NOX 0.171612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 SO2 0.395412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 NOX 0.024912005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 SO2 0.073812005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 NOX 148.202612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 SO2 0.811612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 NOX 4.456412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 SO2 0.024412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 NOX 144.839612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 SO2 0.750012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 NOX 5.014412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 SO2 0.026012009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 NOX 1,356.283612009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 SO2 1.965812009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 NOX 829.858012009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 SO2 1,894.741912009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 NOX 0.011412009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 SO2 0.000212009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 NOX 1,665.609512009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 SO2 2.220912009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 NOX 1,141.284012009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 SO2 2,396.808812009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 NOX 0.012412009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 SO2 0.000312009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 NOX 0.0175Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201244AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 SO2 0.033212009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 NOX 16.844512009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 SO2 0.126812009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 NOX 0.554012009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 SO2 0.569012009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 NOX 27.582012009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 SO2 0.561012009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 NOX 0.060312009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 SO2 0.100112009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 NOX 24.503712009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 SO2 0.241912009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 NOX 0.591612009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 SO2 0.488912009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 NOX 26.585412009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 SO2 0.435112009 ORLANDO UTLITIES COMMISSION0090008 5 2 683 **C NOX 4.536012009 ORLANDO UTLITIES COMMISSION0090008 5 2 683 **C SO2 0.037012009 ORLANDO UTLITIES COMMISSION0090008 6 2 683 **D NOX 6.634012009 ORLANDO UTLITIES COMMISSION0090008 6 2 683 **D SO2 0.069012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 NOX 29.939912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 SO2 0.105612009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 NOX 39.551612009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 SO2 0.145912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 NOX 19.861112009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 SO2 80.702812009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 NOX 68.226412009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 SO2 342.253912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 1 SO2 0.075512009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 2 SO2 0.073212009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 4 55318 2 SO2 0.081012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 NOX 77.052112009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 SO2 0.281012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 NOX 98.3389Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201245AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 SO2 489.397012011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 NOX 0.094112011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 SO2 0.139612011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 NOX 448.493912011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 SO2 2.482412011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 NOX 500.238412011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 SO2 2.454012011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 NOX 0.105612011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 SO2 0.138012011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 NOX 678.057012011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 SO2 3.396012011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 NOX 686.054012011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 SO2 3.418012011 FLORIDA POWER & LIGHT (PPE)0110036 1 1 617PPE1 NOX 43.613312011 FLORIDA POWER & LIGHT (PPE)0110036 1 1 617PPE1 SO2 0.192212011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 NOX 387.032712011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 SO2 1,484.126412011 FLORIDA POWER & LIGHT (PPE)0110036 1 7 617PPE1 NOX 0.012112011 FLORIDA POWER & LIGHT (PPE)0110036 1 7 617PPE1 SO2 0.000412011 FLORIDA POWER & LIGHT (PPE)0110036 2 1 617PPE2 NOX 30.215012011 FLORIDA POWER & LIGHT (PPE)0110036 2 1 617PPE2 SO2 0.136712011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 NOX 303.411012011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 SO2 1,194.452012011 FLORIDA POWER & LIGHT (PPE)0110036 2 6 617PPE2 NOX 0.010012011 FLORIDA POWER & LIGHT (PPE)0110036 2 6 617PPE2 SO2 0.000312011 FLORIDA POWER & LIGHT (PPE) 0110036 3 1 617 PPE3 NOX 604.125312011 FLORIDA POWER & LIGHT (PPE)0110036 3 1 617PPE3 SO2 1.492012011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 NOX 1,478.764812011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 SO2 3,177.451312011 FLORIDA POWER & LIGHT (PPE)0110036 3 6 617PPE3 NOX 0.040912011 FLORIDA POWER & LIGHT (PPE)0110036 3 6 617PPE3 SO2 0.000712011 FLORIDA POWER & LIGHT (PPE) 0110036 4 1 617 PPE4 NOX 540.360412011 FLORIDA POWER & LIGHT (PPE)0110036 4 1 617PPE4 SO2 1.3622Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201246AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 NOX 2,000.326612011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 SO2 4,387.456812011 FLORIDA POWER & LIGHT (PPE)0110036 4 6 617PPE4 NOX 0.050012011 FLORIDA POWER & LIGHT (PPE)0110036 4 6 617PPE4 SO2 0.000912017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 1 3 628 1 NOX 4,054.805012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 1 3 6281 SO2 16,738.693012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 2 4 628 2 NOX 4,910.118012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 2 4 6282 SO2 19,166.410012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 3 2 6285 NOX 12,553.819012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 3 2 6285 SO2 26,650.920012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 4 2 6284 NOX 14,430.849012017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 4 2 6284 SO2 29,763.633012027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 NOX 0.100112027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 SO2 0.015412027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 NOX 2.137912027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 SO2 0.037612027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 NOX 1.256112027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 SO2 0.314212027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 NOX 2.586912027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 SO2 0.189812031 JEA 0310045 16 1 207 1 NOX 27.226812031 JEA 0310045 16 1 207 1 SO2 0.889912031 JEA 0310045 16 2 207 1 NOX 32.253312031 JEA 0310045 16 2 207 1 SO2 128.514112031 JEA 0310045 16 3 207 1 NOX 10,257.372012031 JEA 0310045 16 3 207 1 SO2 6,506.193012031 JEA 0310045 17 1 207 2 NOX 29.475012031 JEA 0310045 17 1 207 2 SO2 0.499612031 JEA 0310045 17 2 207 2 NOX 1,824.894412031 JEA 0310045 17 2 207 2 SO2 3,770.114812031 JEA 0310045 17 3 207 2 NOX 9,860.013512031 JEA 0310045 17 3 207 2 SO2 3,245.016612031 JEA 0310045 26 1 667 2A NOX 103.3139Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201247AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12031 JEA 0310045 26 1 667 2A SO2 69.817112031 JEA 0310045 26 2 667 2A NOX 611.590312031 JEA 0310045 26 2 667 2A SO2 1,338.595912031 JEA 0310045 26 3 667 2A NOX 3.796812031 JEA 0310045 27 1 667 1A NOX 108.698812031 JEA 0310045 27 1 667 1A SO2 70.496012031 JEA 0310045 27 2 667 1A NOX 614.093212031 JEA 0310045 27 2 667 1A SO2 1,440.123012031 JEA 0310045 27 3 667 1A NOX 1.800012031 JEA 0310045 3 1 667 3 NOX 561.382512031 JEA 0310045 3 2 667 3 NOX 186.036812031 JEA 0310045 3 2 667 3 SO2 1,281.108012031 JEA 0310045 3 5 667 3 NOX 0.673712031 JEA 0310047 15 1 666 7 NOX 11.082812031 JEA 0310047 15 2 666 7 NOX 0.097212031 JEA 0310047 15 2 666 7 SO2 0.240012031 JEA 0310485 1 1 7846 1 NOX 9.493012031 JEA 0310485 1 1 7846 1 SO2 0.169012031 JEA 0310485 2 2 7846 2 NOX 36.911012031 JEA 0310485 2 2 7846 2 SO2 1.548012031 JEA 0310485 3 2 7846 3 NOX 41.803012031 JEA 0310485 3 2 7846 3 SO2 1.786012033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 6 NOX 9.683812033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 6 SO2 39.788112033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 7 NOX 1.552012033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 7 SO2 22.070812033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 4 NOX 0.449712033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 4 SO2 1.594612033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 5 NOX 0.306912033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 5 SO2 1.167312033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 6 NOX 0.040212033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 6 SO2 0.165112033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 7 NOX 0.1938Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201248AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 7 SO2 2.756012033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 NOX 1,058.544512033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 SO2 3,753.204712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 NOX 845.807712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 SO2 3,216.858712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 NOX 2,942.815012033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 SO2 12,951.347812033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 NOX 1,488.340212033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 SO2 21,165.054212033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 4 NOX 0.670612033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 4 SO2 2.377912033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 5 NOX 6.423412033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 5 SO2 24.430012033 GULF POWER COMPANY CRIST PLANT 0330045 1 5 641 4 NOX 0.089112033 GULF POWER COMPANY CRIST PLANT 0330045 1 5 641 4 SO2 0.315812049 HARDEE POWER PARTNERS LIMITED 0490015 5 1 50949 CT2B NOX 2.440212049 HARDEE POWER PARTNERS LIMITED 0490015 5 2 50949 CT2B NOX 0.218812049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 1 7380 1 NOX 30.605012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 1 7380 1 SO2 0.558012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 2 7380 1 NOX 0.062012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 2 7380 1 SO2 0.010012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 1 7380 2 NOX 33.606912049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 1 7380 2 SO2 0.653012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 2 7380 2 NOX 0.080112049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 2 7380 2 SO2 0.010012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 1 7380 4A NOX 11.612012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 1 7380 4A SO2 0.140012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 2 7380 4B NOX 11.828012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 2 7380 4B SO2 0.131012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 1 7380 5A NOX 10.297012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 1 7380 5A SO2 0.129012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 2 7380 5B NOX 9.838012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 2 7380 5B SO2 0.1350Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201249AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 1 7380 6A NOX 11.342012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 1 7380 6A SO2 0.150012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 2 7380 6B NOX 10.793012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 2 7380 6B SO2 0.146012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 1 7380 7A NOX 12.812012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 1 7380 7A SO2 0.172012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 2 7380 7B NOX 12.940012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 2 7380 7B SO2 0.171012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 1 7380 8A NOX 10.781012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 1 7380 8A SO2 0.123012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 2 7380 8B NOX 11.032012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 2 7380 8B SO2 0.133012049 VANDOLAH POWER COMPANY, LLC0490043 1 1 55415 GT101 NOX 0.671812049 VANDOLAH POWER COMPANY, LLC0490043 1 1 55415 GT101 SO2 0.448012049 VANDOLAH POWER COMPANY, LLC 0490043 1 2 55415 GT101 NOX 13.507212049 VANDOLAH POWER COMPANY, LLC0490043 2 1 55415 GT201 NOX 2.005412049 VANDOLAH POWER COMPANY, LLC0490043 2 1 55415 GT201 SO2 1.207012049 VANDOLAH POWER COMPANY, LLC0490043 2 2 55415 GT201 NOX 8.514612049 VANDOLAH POWER COMPANY, LLC0490043 3 1 55415 GT301 NOX 2.296312049 VANDOLAH POWER COMPANY, LLC0490043 3 1 55415 GT301 SO2 1.720012049 VANDOLAH POWER COMPANY, LLC0490043 3 2 55415 GT301 NOX 6.959712049 VANDOLAH POWER COMPANY, LLC0490043 4 1 55415 GT401 NOX 0.461912049 VANDOLAH POWER COMPANY, LLC0490043 4 1 55415 GT401 SO2 0.297012049 VANDOLAH POWER COMPANY, LLC0490043 4 2 55415 GT401 NOX 5.560112057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 NOX 10,043.608012057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 SO2 2,999.205012057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 NOX 10,050.939012057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 SO2 2,716.640012057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 NOX 3,838.168012057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 SO2 1,762.555012057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 NOX 1,192.414012057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 SO2 2,396.061012057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A NOX 52.8910Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201250AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A SO2 2.203012057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B NOX 51.293012057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B SO2 2.248012057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C NOX 44.772012057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C SO2 1.862012057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A NOX 60.582012057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A SO2 2.673012057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B NOX 56.355012057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B SO2 2.653012057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C NOX 59.920012057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C SO2 2.673012057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D NOX 614.234012057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D SO2 2.570012061 CITY OF VERO BEACH 0610029 3 1 693 3 NOX 3.791012061 CITY OF VERO BEACH 0610029 3 1 693 3 SO2 0.024012061 CITY OF VERO BEACH 0610029 4 1 693 4 NOX 20.621012061 CITY OF VERO BEACH 0610029 4 1 693 4 SO2 0.089012061 CITY OF VERO BEACH 0610029 5 1 693 **5 NOX 7.658112061 CITY OF VERO BEACH 0610029 5 1 693 **5 SO2 0.143012061 CITY OF VERO BEACH 0610029 5 2 693 **5 NOX 0.001912061 CITY OF VERO BEACH 0610029 5 2 693 **5 SO2 0.058012063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 1 NOX 0.361012063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 1 SO2 1.077312063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 2 NOX 0.423812063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 2 SO2 1.259912063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 2 642 1 NOX 857.996712063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 1 SO2 2,560.767512063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 2 642 2 NOX 813.863212063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 2 SO2 2,419.796112063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 3 642 1 NOX 0.011412063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 3 642 1 SO2 0.041212071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A NOX 151.483012071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A SO2 3.3410Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201251AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B NOX 146.258012071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B SO2 3.183012071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C NOX 160.901012071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C SO2 3.453012071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D NOX 158.289012071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D SO2 3.301012071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E NOX 157.256012071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E SO2 3.400012071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F NOX 151.786012071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F SO2 3.237012071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A NOX 31.692612071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A SO2 0.535312071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A NOX 3.043412071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A SO2 0.660712071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B NOX 2.361712071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B SO2 0.366912071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B NOX 33.670312071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B SO2 0.495112073 CITY OF TALLAHASSEE 0730003 1 1 688 1 NOX 306.707012073 CITY OF TALLAHASSEE 0730003 1 1 688 1 SO2 0.830012073 CITY OF TALLAHASSEE 0730003 31 1 688HC3 NOX 0.022412073 CITY OF TALLAHASSEE 0730003 31 1 688HC3 SO2 1.346612073 CITY OF TALLAHASSEE 0730003 31 2 688HC3 NOX 4.234612073 CITY OF TALLAHASSEE 0730003 31 2 688HC3 SO2 0.192412073 CITY OF TALLAHASSEE 0730003 32 1 688HC4 NOX 0.014512073 CITY OF TALLAHASSEE 0730003 32 1 688HC4 SO2 0.855112073 CITY OF TALLAHASSEE 0730003 32 2 688HC4 NOX 4.316512073 CITY OF TALLAHASSEE 0730003 32 2 688HC4 SO2 0.106912073 CITY OF TALLAHASSEE 0730003 4 1 688 2 NOX 393.086812073 CITY OF TALLAHASSEE 0730003 4 1 688 2 SO2 1.399912073 CITY OF TALLAHASSEE 0730003 4 2 6882 NOX 90.391212073 CITY OF TALLAHASSEE 0730003 4 2 688 2 SO2 492.879112081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 NOX 1,021.5074Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201252AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 SO2 6,212.965512081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 NOX 0.020112081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 SO2 0.001012081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 NOX 269.404512081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 SO2 1.844512081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 NOX 1,147.361412081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 SO2 5,582.577112081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 NOX 0.023012081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 SO2 0.000912081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 NOX 303.983612081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 SO2 1.664912081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A NOX 51.572012081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A SO2 3.584012081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B NOX 57.014012081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B SO2 3.661012081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C NOX 51.826012081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C SO2 3.512012081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D NOX 58.812012081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D SO2 3.795012085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 NOX 1,028.914812085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 SO2 3.586112085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 NOX 875.301912085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 SO2 4,960.278312085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 NOX 0.019312085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 SO2 0.000512085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A NOX 49.890812085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A SO2 3.463312085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A NOX 0.037212085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A SO2 0.000712085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B NOX 53.962912085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B SO2 3.958712085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B NOX 0.108112085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B SO2 0.0023Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201253AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C NOX 54.478412085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C SO2 3.914712085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C NOX 0.742612085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C SO2 0.013312085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D NOX 48.812912085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D SO2 3.901012085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D NOX 1.142112085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D SO2 0.019012085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 NOX 1,007.402312085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 SO2 3.238712085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 NOX 1,065.328112085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 SO2 5,568.798712085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 NOX 0.019612085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 SO2 0.000612085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A NOX 191.378012085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A SO2 3.428012085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B NOX 231.617012085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B SO2 3.429012085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A NOX 246.151012085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A SO2 3.443012085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B NOX 183.877012085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B SO2 3.269012086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 NOX 12.297012086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 SO2 0.072012086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 NOX 63.730012086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 SO2 0.381012086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 NOX 141.521112086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 SO2 0.505012086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 NOX 1,330.613812086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 SO2 4,218.407312086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 NOX 0.022112086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 SO2 0.000612086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B NOX 35.7690Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201254AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B SO2 3.196912086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B NOX 2.018012086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B SO2 0.017112086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C NOX 33.777012086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C SO2 3.130812086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C NOX 1.591012086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C SO2 0.013212086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D NOX 36.602312086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D SO2 3.165212086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D NOX 2.322712086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D SO2 0.015812086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 NOX 164.962712086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 SO2 0.492312086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 NOX 1,369.479012086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 SO2 3,630.897212086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 NOX 0.021212086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 SO2 0.000512086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A NOX 33.022012086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A SO2 3.190112086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A NOX 1.779012086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A SO2 0.014912087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 NOX 1.431012087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 SO2 1.465012095 ORLANDO COGEN LIMITED, L.P.0950203 1 1 54466 1 NOX 216.196012095 ORLANDO COGEN LIMITED, L.P.0950203 1 1 54466 1 SO2 2.311012095 ORLANDO UTILITIES COMMISSION0950137 1 2 564 1 NOX 10.383912095 ORLANDO UTILITIES COMMISSION 0950137 1 2 564 1 SO2 6.027212095 ORLANDO UTILITIES COMMISSION0950137 1 3 564 1 NOX 6,043.701012095 ORLANDO UTILITIES COMMISSION0950137 1 3 564 1 SO2 4,603.364412095 ORLANDO UTILITIES COMMISSION 0950137 1 4 564 1 NOX 114.321512095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 NOX 0.443612095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 SO2 1.239512095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 NOX 2.1343Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201255AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 SO2 1.528412095 ORLANDO UTILITIES COMMISSION0950137 2 3 564 2 NOX 2,571.211512095 ORLANDO UTILITIES COMMISSION0950137 2 3 564 2 SO2 1,854.051512095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 NOX 0.186912095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 SO2 1.235112095 ORLANDO UTILITIES COMMISSION0950137 2 5 564 2 NOX 18.991412095 ORLANDO UTILITIES COMMISSION0950137 26 1 55821 25 NOX 64.460012095 ORLANDO UTILITIES COMMISSION0950137 26 1 55821 25 SO2 1.517612095 ORLANDO UTILITIES COMMISSION0950137 26 2 55821 25 NOX 0.022012095 ORLANDO UTILITIES COMMISSION0950137 26 2 55821 25 SO2 0.052412095 ORLANDO UTILITIES COMMISSION0950137 27 1 55821 26 NOX 63.585912095 ORLANDO UTILITIES COMMISSION0950137 27 1 55821 26 SO2 1.425312095 ORLANDO UTILITIES COMMISSION0950137 27 2 55821 26 NOX 0.030112095 ORLANDO UTILITIES COMMISSION0950137 27 2 55821 26 SO2 0.040712095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 NOX 46.654012095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 SO2 0.169012095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 NOX 0.816012095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 SO2 0.169012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 10 1 8049 **10 NOX 36.604012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 10 18049 **10 SO2 0.822012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 11 1 8049 **11 NOX 14.856012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 11 1 8049 **11 SO2 16.049012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 18 2 8049 **12 NOX 22.847012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 18 28049 **12 SO2 0.662012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 19 2 8049 **13 NOX 22.842012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 19 28049 **13 SO2 0.652012097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 21 2 8049 **14 NOX 27.089012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 21 28049 **14 SO2 0.860012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 7 1 8049 **7 NOX 39.619012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 7 18049 **7 SO2 0.805012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 8 1 8049 **8 NOX 42.024012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 8 18049 **8 SO2 0.771012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 9 1 8049 **9 NOX 46.3020Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201256AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 9 18049 **9 SO2 0.822012097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 NOX 2.551012097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 SO2 0.018012097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 NOX 35.842012097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 SO2 0.637012097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 NOX 48.746012097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 SO2 2.666012097 RELIANT ENERGY FLORIDA, LLC 0970071 1 1 55192 OSC1 NOX 23.577012097 RELIANT ENERGY FLORIDA, LLC 0970071 1 1 55192 OSC1 SO2 0.508012097 RELIANT ENERGY FLORIDA, LLC 0970071 2 1 55192 OSC2 NOX 20.982012097 RELIANT ENERGY FLORIDA, LLC 0970071 2 1 55192 OSC2 SO2 0.443012097 RELIANT ENERGY FLORIDA, LLC 0970071 3 1 55192 OSC3 NOX 1.959412097 RELIANT ENERGY FLORIDA, LLC 0970071 3 1 55192 OSC3 SO2 0.013712097 RELIANT ENERGY FLORIDA, LLC 0970071 3 2 55192 OSC3 NOX 1.439612097 RELIANT ENERGY FLORIDA, LLC 0970071 3 2 55192 OSC3 SO2 0.402312099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673S-3 NOX 9.185012099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673S-3 SO2 0.021012099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 NOX 205.235412099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 SO2 0.584812099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 NOX 1,134.597412099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 SO2 2,783.245112099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 NOX 0.052212099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 SO2 0.001112099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 NOX 811.024212099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 SO2 1.892812099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 NOX 1,442.817312099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 SO2 2,898.827912099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 NOX 0.078512099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 SO2 0.001312101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 1 3 8048 1 NOX 3,501.590012101 FLORIDA POWER CORPDBAPROGRESS ENERGYFL 1010017 1 3 80481 SO2 13,162.815012101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 2 2 8048 2 NOX 3,075.462012101 FLORIDA POWER CORPDBAPROGRESS ENERGYFL 1010017 2 2 80482 SO2 13,875.6460Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201257AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 11 55414 GT101 NOX 8.786412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 11 55414 GT101 SO2 2.306212101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 12 55414 GT101 NOX 54.757612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 12 55414 GT101 SO2 1.162812101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 21 55414 GT201 NOX 8.169212101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 21 55414 GT201 SO2 2.239612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 22 55414 GT201 NOX 51.803812101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 22 55414 GT201 SO2 1.034412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 31 55414 GT301 NOX 10.911612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 31 55414 GT301 SO2 3.004512101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 32 55414 GT301 NOX 54.237412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 32 55414 GT301 SO2 1.176512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 11 634 1 NOX 0.578312103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 11 634 1 SO2 4.443312103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 NOX 610.866712103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 SO2 3,345.872812103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 13 634 1 SO2 0.055912103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 NOX 459.239512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 SO2 2,413.285612103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 25 634 2 NOX 0.004912103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 25 634 2 SO2 0.058112103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 26 634 2 NOX 0.020612103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 26 634 2 SO2 0.141212103 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1030011 3 1634 3 SO2 43.956012103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 NOX 1,556.693012103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 SO2 6,619.406112103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 34 634 3 SO2 2.550512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 35 634 3 SO2 0.147412105 APP, LP; APEC, LLC; CCFC 1050221 1 1 54658 1 NOX 136.818012105 APP, LP; APEC, LLC; CCFC 1050221 1 1 546581 SO2 1.909012105 APP, LP; APEC, LLC; CCFC 1050221 6 1 558336 NOX 27.074012105 APP, LP; APEC, LLC; CCFC 1050221 6 1 558336 SO2 0.183012105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412 CT1 NOX 147.8600Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201258AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412CT1 SO2 2.442012105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412 CT2 NOX 143.753012105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412CT2 SO2 2.625012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050223 1 27699 1 NOX 95.018012105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050223 1 2 7699 1 SO2 1.945012105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 1 1 7302 1A NOX 105.966012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 1 1 7302 1A SO2 2.179012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 1 7302 2A NOX 62.226012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 1 7302 2A SO2 3.358712105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 2 7302 2A SO2 0.003312105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 1 7302 2B NOX 64.592012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 1 7302 2B SO2 3.067612105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 2 7302 2B SO2 0.004412105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 1 7302 3A NOX 52.257012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 1 7302 3A SO2 3.340612105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 2 7302 3A SO2 0.000412105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 1 7302 3B NOX 46.516012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 1 7302 3B SO2 1.562112105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 2 7302 3B SO2 1.743912105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 2 1 7302 1B NOX 109.539012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 2 1 7302 1B SO2 1.904012105 LAKELAND ELECTRIC 1050003 8 1675 **8 NOX 0.033012105 LAKELAND ELECTRIC 1050003 8 1675 **8 SO2 0.445012105 LAKELAND ELECTRIC 1050003 8 2 675**8 NOX 41.090012105 LAKELAND ELECTRIC 1050004 1 1676 1 NOX 50.064412105 LAKELAND ELECTRIC 1050004 1 1 676 1 SO2 0.101212105 LAKELAND ELECTRIC 1050004 1 2676 1 NOX 32.260612105 LAKELAND ELECTRIC 1050004 1 2 676 1 SO2 233.214012105 LAKELAND ELECTRIC 1050004 1 3 676 1 NOX 0.103012105 LAKELAND ELECTRIC 1050004 1 3 676 1 SO2 0.829812105 LAKELAND ELECTRIC 1050004 28 2676 5 NOX 97.427012105 LAKELAND ELECTRIC 1050004 282 676 5 SO2 2.510012105 LAKELAND ELECTRIC 1050004 5 1676 2 NOX 66.8170Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201259AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12105 LAKELAND ELECTRIC 1050004 5 1 676 2 SO2 0.388012105 LAKELAND ELECTRIC 1050004 5 2 676 2 NOX 3.726012105 LAKELAND ELECTRIC 1050004 5 2676 2 SO2 10.339012105 LAKELAND ELECTRIC 1050004 6 3 676 3 NOX 5,229.709112105 LAKELAND ELECTRIC 1050004 6 3 676 3 SO2 7,205.791012105 LAKELAND ELECTRIC 1050004 6 4 676 3 NOX 1.946012105 LAKELAND ELECTRIC 1050004 6 4 676 3 SO2 0.014012105 LAKELAND ELECTRIC 1050004 6 9676 3 NOX 12.617912105 LAKELAND ELECTRIC 1050004 6 9676 3 SO2 17.391012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 NOX 41.176012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 SO2 0.503012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 NOX 37.909012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 SO2 0.462012105 POLK POWER PARTNERS, L.P.1050217 1 1 54426 1 NOX 66.706012105 POLK POWER PARTNERS, L.P.1050217 1 1 54426 1 SO2 1.084012105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 NOX 396.447012105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 SO2 1,069.837012105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 NOX 16.673012105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 SO2 0.521012105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 NOX 13.307012105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 SO2 0.256012105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 NOX 11.923012105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 SO2 0.220012105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 NOX 12.659012105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 SO2 0.309012107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 NOX 421.684112107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 SO2 0.641312107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 NOX 0.128912107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 SO2 0.116712107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 NOX 468.859112107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 SO2 0.661812107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 NOX 0.141912107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 SO2 0.1192Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201260AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 NOX 348.248412107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 SO2 0.540912107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 NOX 0.072612107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 SO2 0.067112107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 NOX 354.333312107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 SO2 0.555812107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 NOX 0.082712107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 SO2 0.077212107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 1 136 1 NOX 21.226512107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 1 136 1 SO2 25.507112107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 2 136 1 NOX 8,013.601612107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 2 136 1 SO2 9,629.657912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 3 136 1 NOX 392.904912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 3 136 1 SO2 472.140012107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 1 136 2 NOX 24.185112107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 1 136 2 SO2 25.529512107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 2 136 2 NOX 9,001.978312107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 2 136 2 SO2 9,502.365212107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 3 136 2 NOX 644.192712107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 3 136 2 SO2 680.001212111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 NOX 3.072012111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 SO2 0.015012111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 NOX 3.948012111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 SO2 0.027012113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 NOX 2.574012113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 SO2 0.013012121 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1210003 1 3638 1 NOX 94.405012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 1 3 638 1 SO2 161.700012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 NOX 138.813012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 SO2 497.796012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 NOX 206.116012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 SO2 219.874012127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 NOX 26.2474Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201261AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 SO2 0.045012127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 NOX 102.441212127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 SO2 301.320912127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 NOX 0.004412127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 SO2 0.000112127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A NOX 162.960012127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A SO2 3.287012127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B NOX 164.969012127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B SO2 3.272012127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C NOX 165.927012127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C SO2 3.312012127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D NOX 164.230012127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D SO2 3.214012127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A NOX 159.921012127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A SO2 3.294012127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B NOX 169.291012127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B SO2 3.352012127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C NOX 176.756012127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C SO2 3.515012127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D NOX 147.268012127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D SO2 2.987012127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 15 1 6046 **7 NOX 25.011012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 15 16046 **7 SO2 7.871012127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 16 1 6046 **8 NOX 24.743012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 16 16046 **8 SO2 7.889012127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 17 1 6046 **9 NOX 21.178012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 17 16046 **9 SO2 7.258012127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 18 1 6046 **10 NOX 12.892012127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 18 1 6046 **10 SO2 27.775012129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 2 689 8 NOX 0.009512129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 2 689 8 SO2 0.697612129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 3 689 8 NOX 155.989512129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 3 689 8 SO2 3.3884Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201262AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 7 1 689 7 NOX 65.700012129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 7 1 689 7 SO2 0.16501.9.8.4 GeorgiaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions13015 Ga Power Company - Plant Bowen 01500011 S1 1 703 1BLR NOX 3,551.565013015 Ga Power Company - Plant Bowen 01500011 S2 1 703 2BLR NOX 4,843.621013015 Ga Power Company - Plant Bowen 01500011 S3 1 703 3BLR NOX 5,702.325013015 Ga Power Company - Plant Bowen 01500011 S4 1 703 4BLR NOX 4,357.206013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 1 NOX 1,149.006013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 NOX 1,033.948013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 SO2 1,878.778013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 NOX 2,049.303013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 SO2 3,622.665013051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 NOX 80.570013051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 SO2 124.171013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 NOX 2,257.208013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 SO2 13,983.341013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB2 SO2 14,554.921013077 Ga Power Company - Plant Yates 07700001 ST1 1 728 Y2BR NOX 1,528.460013077 Ga Power Company - Plant Yates 07700001 ST1A 1 728 Y1BR NOX 1,426.715013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR NOX 1,612.004013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR SO2 9,213.658013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR NOX 1,432.379013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR SO2 8,636.783013095 Ga Power Company - Plant Mitchell 09500002 ST3 1 727 3 NOX 1,985.073013103 Effingham County Power, LLC 10300012 S2 CTG2 55406 2 NOX 42.484013103 Ga Power Co Plt Mcintosh 10300003 S1 1 6124 1 NOX 2,092.398013115 Ga Power Company - Plant Hammond 11500003 ST2 1 708 4 NOX 4,176.184013127 Ga Power Company - Plant McManus 12700004 ST01 2 715 1 NOX 18.480013127 Ga Power Company - Plant McManus 12700004 ST01 2 715 2 NOX 27.513013149 Ga Power Company - Plant Wansley 14900001 ST01 1 6052 1 NOX 5,831.988013149 Ga Power Company - Plant Wansley 14900001 ST02 1 6052 2 NOX 8,026.3610Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201263AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions13149 Ga Power Company - Plant Wansley 14900001 ST04 1 6052 6A NOX 37.954013149 Ga Power Company - Plant Wansley 14900001 ST05 1 6052 6B NOX 34.908013149 Ga Power Company - Plant Wansley 14900001 ST06 1 6052 7A NOX 39.084013149 Ga Power Company - Plant Wansley 14900001 ST07 1 6052 7B NOX 40.719013207 Ga Power Company - Plant Scherer 20700008 ST2 1 6257 2 NOX 4,670.316013207 Ga Power Company - Plant Scherer 20700008 ST4 1 6257 4 NOX 4,672.102013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 NOX 4,161.140013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 SO2 17,707.594013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 NOX 4,561.670013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 SO2 19,404.389013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 3 SO2 28,422.559013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 NOX 6,559.262013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 SO2 32,828.195013297 DOYLE GENERATING FACILITY 29700041 41 1 55244 CTG-5 NOX 6.43701.9.8.5 KentuckyCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21049 East Ky Power Coop 00003 001 1 1385 1 NOX 473.785021049 East Ky Power Coop 00003 001 1 1385 1 SO2 1,097.579021049 East Ky Power Coop 00003 002 1 1385 2 NOX 482.674021049 East Ky Power Coop 00003 002 1 1385 2 SO2 1,094.589021049 East Ky Power Coop 00003 003 1 1385 3 SO2 2,563.177021127 Kentucky Power Co-Big Sandy Plant 00003 01 1 1353 BSU1 NOX 3,393.826021127 Kentucky Power Co-Big Sandy Plant 00003 01 1 1353 BSU1 SO2 10,636.324221127 Kentucky Power Co-Big Sandy Plant 00003 01 2 1353 BSU1 NOX 0.908021127 Kentucky Power Co-Big Sandy Plant 00003 01 2 1353 BSU1 SO2 0.500821127 Kentucky Power Co-Big Sandy Plant 00003 02 1 1353 BSU2 NOX 11,585.034121127 Kentucky Power Co-Big Sandy Plant 00003 02 1 1353 BSU2 SO2 36,112.387421127 Kentucky Power Co-Big Sandy Plant 00003 02 2 1353 BSU2 NOX 3.136921127 Kentucky Power Co-Big Sandy Plant 00003 02 2 1353 BSU2 SO2 1.725621167 KY Utilities Co - Brown Station 00001 023-29 10 1355 9 NOX 3.787021167 KY Utilities Co - Brown Station 00001 023-29 11 1355 9 NOX 6.196021167 KY Utilities Co - Brown Station 00001 023-29 12 1355 10 NOX 6.2687Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201264AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21167 KY Utilities Co - Brown Station 00001 023-29 13 1355 10 NOX 0.783321167 KY Utilities Co - Brown Station 00001 023-29 14 1355 11 NOX 4.064021167 KY Utilities Co - Brown Station 00001 023-29 2 1355 5 NOX 10.923121167 KY Utilities Co - Brown Station 00001 023-29 3 1355 5 NOX 0.011921167 KY Utilities Co - Brown Station 00001 023-29 4 1355 6 NOX 19.894021167 KY Utilities Co - Brown Station 00001 023-29 5 1355 6 NOX 0.061021167 KY Utilities Co - Brown Station 00001 023-29 6 1355 7 NOX 71.180721167 KY Utilities Co - Brown Station 00001 023-29 7 1355 7 NOX 0.939321167 KY Utilities Co - Brown Station 00001 023-29 8 1355 8 NOX 19.346221167 KY Utilities Co - Brown Station 00001 023-29 9 1355 8 NOX 0.208821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 1 1378 1 SO2 11,733.637721177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 2 1378 1 SO2 2.961321177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 3 1378 1 SO2 460.585621177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 4 1378 1 SO2 0.062021177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 5 1378 1 SO2 0.077421177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 1 1378 2 SO2 17,824.133121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 2 1378 2 SO2 4.498121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 3 1378 2 SO2 699.658921177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 4 1378 2 SO2 0.107821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 1 1378 3 SO2 3,761.212121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 2 1378 3 SO2 0.949221177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 3 1378 3 SO2 147.640521177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 4 1378 3 SO2 0.051921177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 5 1378 3 SO2 0.024321183 Western KY Energy Corp - Wilson Station 00069 EU-01 1 6823 W1 NOX 6,598.158021199 East Ky Power Coop 00005 001 1 1384 1 NOX 765.925921199 East Ky Power Coop 00005 001 1 1384 1 SO2 3,495.665921199 East Ky Power Coop 00005 001 2 1384 1 NOX 777.203121199 East Ky Power Coop 00005 001 2 1384 1 SO2 3,242.441121199 East Ky Power Coop 00005 002 1 1384 2 NOX 1,973.138721199 East Ky Power Coop 00005 002 1 1384 2 SO2 8,877.374721199 East Ky Power Coop 00005 002 2 1384 2 NOX 1,022.560321199 East Ky Power Coop 00005 002 2 1384 2 SO2 4,205.4283Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201265AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21233 Western KY Energy Corp - Green Station 00052 EU01G1 1 6639 G1 NOX 2,650.902021233 Western KY Energy Corp - Green Station 00052 EU02G2 1 6639 G2 NOX 2,906.247021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU01 1 1383 R1 SO2 6,735.594021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU02 1 1382 H1 SO2 1,786.966021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU03 1 1382 H2 SO2 1,901.45701.9.8.6 Kentucky – Jefferson CountyNo issues identified.1.9.8.7 MississippiNo changes requested by State.1.9.8.8 North CarolinaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 NOX 2,289.439037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 SO2 7,552.402037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 NOX 2,677.070037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 SO2 7,099.639037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 NOX 4,963.180037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 SO2 7,617.807037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 NOX 4,731.177037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 SO2 1,872.107037071 Duke Energy Carolinas, LLC - Riverbend SteamStation 3707100040 10 S-8 2732 10 NOX 665.658037071 Duke Energy Carolinas, LLC - Riverbend SteamStation 3707100040 10 S-8 2732 10 SO2 4,858.990037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7 S-5 2732 7 NOX 489.186037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7S-5 2732 7 SO2 3,329.180037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8 S-6 2732 8 NOX 472.693037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8S-6 2732 8 SO2 2,908.216037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9 S-7 2732 9 NOX 602.427037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9S-7 2732 9 SO2 4,810.388037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES1 S-1 2718 1 NOX 853.155037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES1 S-1 2718 1 SO2 7,260.767037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES2 S-2 2718 2 NOX 821.529037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES2 S-2 2718 2 SO2 7,082.632037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-3 2718 3 NOX 1,426.5220Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201266AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-3 2718 3 SO2 12,391.614037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-4 2718 4 NOX 1,499.587037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-4 2718 4 SO2 11,576.642037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-5 2718 5 NOX 1,836.973037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-5 2718 5 SO2 12,238.267037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES6 S-7 2718 1 NOX 0.020037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES6 S-7 2718 1 SO2 0.050037129 Carolina Power_Light Company d/b/a ProgressEnergy Caro 3712900036 UNIT 1 S-1 2713 1 NOX 980.312037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT1 S-1 2713 1 SO2 3,458.972037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT1 S-1 2713 2 NOX 1,212.738037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT1 S-1 2713 2 SO2 4,241.526037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A NOX 723.611037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A SO2 12,168.034037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B NOX 639.711037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B SO2 10,642.445037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A NOX 1,208.967037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A SO2 13,704.153037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B NOX 1,162.753037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B SO2 13,152.244037145 Progress Energy - Roxboro Plant 3714500029 EP4 S-4 2712 4B NOX 0.692437145 Progress Energy - Roxboro Plant 3714500029 EP4 S-4 2712 4B SO2 6.753337145 Progress Energy - Roxboro Plant 3714500029 EP4 S-999 2712 4B NOX 720.844637145 Progress Energy - Roxboro Plant 3714500029 EP4 S-999 2712 4B SO2 7,050.866737145 Progress Energy - Roxboro Plant 3714500029 EP4a S-14 2712 4A NOX 804.974037145 Progress Energy - Roxboro Plant 3714500029 EP4a S-14 2712 4A SO2 7,905.259037157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP2S-2 2723 2 SO2 2,040.133237157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3A S-3 2723 3 NOX 445.532237157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3AS-3 2723 3 SO2 1,925.926637157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3B S-4 2723 3 NOX 237.848837157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3BS-4 2723 3 SO2 2,017.656437157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP5 S-6 2723 1 NOX 2.224037157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 NOX 0.992837157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 SO2 0.2799Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201267AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 NOX 0.089437157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 SO2 0.289937157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 NOX 2.202337157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 SO2 0.245837157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 NOX 3.071637157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 SO2 0.209037157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 NOX 3.071637157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 SO2 0.209037157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 SO2 0.052337159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 NOX 152.109037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 SO2 652.741037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 NOX 148.381037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 SO2 625.414037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 NOX 221.838037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 SO2 794.919037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 NOX 581.569037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 SO2 4,265.884037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 NOX 541.7360Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201268AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 SO2 3,921.568037159 Duke Power Company, LLC - Buck SteamStation 3715900004 ES9C S-9 2720 5 NOX 0.518037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1 S-1 2721 1 NOX 229.690237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1 S-1 2721 1 SO2 715.472937161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2 S-2 2721 2 NOX 279.299037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2 S-2 2721 2 SO2 996.333037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3 S-3 2721 3 NOX 478.600037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3 S-3 2721 3 SO2 1,586.277037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4 S-4 2721 4 NOX 512.311037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4 S-4 2721 4 SO2 1,632.625037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 1 NOX 3.593237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 1 SO2 11.803237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 5 NOX 995.811037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 5 SO2 22,623.225037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc.S-10 2721 2 NOX 0.060037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc.S-10 2721 2 SO2 0.010037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1S-1 8042 1 NOX 1,300.686037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1S-1 8042 1 SO2 38,355.698037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2S-2 8042 2 NOX 2,119.973237169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2S-2 8042 2 SO2 48,031.770037169 Duke Energy Carolinas, LLC - Belews CreekSteam Station 3716900004 F-1 S-12 8042 2 NOX 0.159837169 Duke Energy Carolinas, LLC - Belews CreekSteam Station 3716900004 F-1 S-12 8042 2 SO2 0.03001.9.8.9 North Carolina – Buncombe CountyNo affected facilities in the county.1.9.8.10 North Carolina – Forsyth CountyNo affected facilities in the county.1.9.8.11 North Carolina – Mecklenburg CountyNo affected facilities in the county.Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201269AMEC1.9.8.12 South CarolinaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions45021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 NOX 37.407045021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 SO2 0.613045021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 NOX 27.937045021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 SO2 0.421045021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 NOX 43.522045021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 SO2 0.659045021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 NOX 26.817045021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 SO2 0.554045053 SCE&G JASPER1360-0026 11 55927 CT01NOX 30.464045053 SCE&G JASPER1360-0026 11 55927 CT01 SO2 1.571045053 SCE&G JASPER1360-0026 21 55927 CT02NOX 37.633045053 SCE&G JASPER1360-0026 21 55927 CT02 SO2 2.238045053 SCE&G JASPER1360-0026 31 55927 CT03NOX 33.186045053 SCE&G JASPER1360-0026 31 55927 CT03 SO2 1.60401.9.8.13 TennesseeNo affected facilities.1.9.8.14 Tennessee – Davidson County (Nashville)No affected facilities in the county.1.9.8.15 Tennessee – Hamilton County (Chattanooga)No affected facilities in the county.1.9.8.16 Tennessee – Knox County (Knoxville)No affected facilities in the county.1.9.8.17 Tennessee – Shelby County (Memphis)No issues identified.1.9.8.18 VirginiaNo issues identified.1.9.8.19 West VirginiaNo changes requested by State as a result of the CEMS review. West Virginiadid submit revised records for 70 emission releasepoints forPM10-PRI and PM25-PRI. Those records were inserted into the database at the time that the otherCEM related changes were made.

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# 1.9.8.20 Latitude/Longitude Changes

Appendix A lists the State/ County FIPS code, the State Facility ID , the Name of the Facility, the

Emission Release point ID and the new Latitude and Longitude for thos e records that were replaced

based on the quality assurance of latitude and longit ude values performed by GA EPD staff as part

of the Version 1.10a update.

1.10 2007 POINT SOURCE EMISSION SUMMARY

This section presents State-level summaries of the annual point source emissions by pollutant in the

2007 SEMAP version 1.10a inventory and compares the emissions to the 2002 VISTAS Best and

Final inventory. For most Stat es and pollutants, point source em issions have decreased from 2002

to 2007.

Exhibit 7 shows that CO emissions in the SEMAP region have decreased by about 30 percent

between 2002 and 2007. Exhibit 8 shows that mo st of the point source CO emissions (about

81 percent) come from nonEGUs that are not re quired to report emissions to CAMD.

Exhibit 9 shows that 

# NH 3 

# emissions in the SEMAP region ha ve remained about the same in 2002

and 2007, although 

# NH 3 

# emissions increased substantially in some States while decreasing in

others. Exhibit 10 shows that most of the point source 

# NH 3 

# emissions (about 90 percent) come from

nonEGUs that are not required to report emissions to CAMD.

Exhibit 11 shows that NOx emi ssions have decreased by about 26 per cent between 2002 and 2007.

All States showed a decreas e in NOx emissions from point source s. Exhibit 12 shows that about 69

percent of the point source NOx emissions come from EGUs that are required to report emissions to

CAMD. Another 28 percent of t he NOx emissions result from nonE GUs that are not required to

report emissions to CAMD.

Exhibit 13 shows that PM10-PRI emissions in the SEMAP region have decreased by about

7 percent between 2002 and 2007, al though PM10-PRI emissions incr eased substantially in some

States while decreasing in others. Exhibit 14 shows that about 46 per cent of the point source PM10-

PRI emissions come from EGUs that are required to report emissions to CAMD. Another 53 percent

of the PM10-PRI emissions result from nonEGUs that are not required to report emissions to CAMD.

For PM, the emissions presented in Exhibit 13 show the values init ially used for WV based on the

data submitted as described in se ction 1.9.8.19. After modeling had already been conducted, WV

indicated that they believed that th e values used in version 1.9 of t he inventory were actually correct

and requested that the emissions be changed. Since modeling had already been performed, SEMAP

decided to replace the data in the inventory files but did not perform new modeling runs. Appendix B

shows the differences betw een the version 1.9 and version 1.10a in ventories for the records that WV

initially asked to be revised.

Exhibit 15 shows that PM25-PRI emissions in the SEMAP region have decreased by about

3 percent between 2002 and 2007, al though PM25-PRI emissions incr eased substantially in some

States while decreasing in others. Exhibit 16 shows that about 45 per cent of the point source PM25-

PRI emissions come from EGUs that are required to report emissions to CAMD. Another 54 percent

of the PM25-PRI emissions result from nonEGUs that are not required to report emissions to CAMD.

Exhibit 17 shows that 

# SO

2 

# emissions in the SEMAP region ha ve decreased by about 15 percent

between 2002 and 2007. All States ex cept Georgia showed a decrease in 

# SO

2 

# emissions. Exhibit

18 shows that most of the point source 

# SO

2 

# emissions (about 87 percent ) come from EGUs that are

required to report emissions to CAMD. Another 11 percent of the 

# SO

2 

# emissions result from

nonEGUs that are not required to report emissions to CAMD.

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# Exhibit 19 shows that VOC emissions in the SEMAP region have decreased by about 21 percent

between 2002 and 2007. Exhibit 20 shows that nearly all of the point source VOC emissions (about

97 percent) result from nonEGUs that are not required to report emissions to CAMD.

The reasons for the differences between 2002 and 2007 are many and vary by State, facility, and

pollutant. Examples include: 1) new controls added between 2002 and 2007; 2) change in emission

factors or source test data; 3) inclusion of PM condensables that were not included in 2002; 4) more

{or less} facilities in 2002 inventory than in 2007 in ventory; 5) new sources that came online between

2002 and 2007; 6) different fuels used in 2007 than in 2002; 7) industry spec ific economic growth or

contraction between 2002 and 2007 ; 8) facility or emission unit cl osures; and 9) errors in 2002

inventory.

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# Exhibit 7 – 2002 and 2007 Point Source CO Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 185,550 119,344 -36%

Florida 139,045 111,280 -20%

Georgia 140,561 82,547 -41%

Kentucky 122,555 82,553 -33%

Mississippi 59,871 40,294 -33%

North Carolina 64,461 66,811 4%

South Carolina 63,305 60,375 -5%

Tennessee 122,348 51,185 -58%

Virginia 70,688 72,029 2%

West Virginia 100,220 65,230 -35%

SEMAP 1,068,604 751,648 -30%



# Exhibit 8 – 2007 Point Source CO Emissions by Category (tons/year)

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# Exhibit 9 – 2002 and 2007 Point Source 

# NH 3 

# Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 2,200 2,191 0%

Florida 1,657 1,661 0%

Georgia 3,697 6,046 64%

Kentucky 1,000 113 -89%

Mississippi 1,359 1,640 21%

North Carolina 1,234 1,707 38%

South Carolina 1,553 1,125 -28%

Tennessee 1,817 1,429 -21%

Virginia 3,230 1,830 -43%

West Virginia 453 366 -19%

SEMAP 18,200 18,107 -1%



# Exhibit 10 – 2007 Point Source 

# NH 3 

# Emissions by Category (tons/year)

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# Exhibit 11 – 2002 and 2007 Point Source NOx Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 244,348 197,963 -19%

Florida 302,834 237,473 -22%

Georgia 196,767 154,041 -22%

Kentucky 237,209 210,213 -11%

Mississippi 104,661 98,183 -6%

North Carolina 196,782 100,379 -49%

South Carolina 130,394 81,220 -38%

Tennessee 221,652 144,763 -35%

Virginia 147,300 112,938 -23%

West Virginia 277,589 188,629 -32%

SEMAP 2,059,536 1,525,801 -26%



# Exhibit 12 – 2007 Point Source NOx Emissions by Category (tons/year)

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# Exhibit 13 – 2002 and 2007 Point Source PM10-PRI Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 32,886 34,776 6%

Florida 57,243 35,796 -37%

Georgia 32,834 33,214 1%

Kentucky 21,326 30,678 44%

Mississippi 21,106 12,368 -41%

North Carolina 36,592 42,995 17%

South Carolina 35,542 30,605 -14%

Tennessee 49,814 27,874 -44%

Virginia 17,211 19,203 12%

West Virginia 22,076 35,457 61%

SEMAP 326,630 302,966 -7%



# Exhibit 14 – 2007 Point Source PM10-PRI Emissions by Category (tons/year)

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# Exhibit 15 – 2002 and 2007 Point Source PM25-PRI Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 23,291 24,930 7%

Florida 46,148 28,418 -38%

Georgia 22,401 25,059 12%

Kentucky 14,173 21,111 49%

Mississippi 11,044 8,731 -21%

North Carolina 26,998 33,444 24%

South Carolina 27,399 23,493 -14%

Tennessee 39,973 22,144 -45%

Virginia 12,771 14,875 16%

West Virginia 15,523 30,552 97%

SEMAP 239,721 232,756 -3%



# Exhibit 16 – 2007 Point Source PM25-PRI Emissions by Category (tons/year)

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# Exhibit 17 – 2002 and 2007 Point Source SO2 Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 544,309 526,620 -3%

Florida 518,721 379,590 -27%

Georgia 568,731 683,358 20%

Kentucky 518,086 410,414 -21%

Mississippi 103,388 94,978 -8%

North Carolina 522,113 420,438 -19%

South Carolina 259,916 216,125 -17%

Tennessee 413,755 287,668 -30%

Virginia 305,106 243,048 -20%

West Virginia 570,153 428,350 -25%

SEMAP 4,324,278 3,690,588 -15%



# Exhibit 18 – 2007 Point Source SO2 Emissions by Category (tons/year)

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# Exhibit 19 – 2002 and 2007 Point Source VOC Emissions by State (tons/year)

STATE 2002 2007 Change

Alabama 49,332 38,877 -21%

Florida 40,995 33,683 -18%

Georgia 34,952 36,717 5%

Kentucky 46,321 47,679 3%

Mississippi 43,852 34,587 -21%

North Carolina 62,170 48,349 -22%

South Carolina 38,927 29,281 -25%

Tennessee 85,254 48,103 -44%

Virginia 43,906 35,618 -19%

West Virginia 15,775 12,503 -21%

SEMAP 461,484 365,397 -21%



# Exhibit 20 – 2007 Point Source VOC Emissions by Category (tons/year)

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# 1.11 DATA FILES

These files are accessible on the MACTEC ftp site in the following location:

Address: ftp.mactec.com

Login ID: externalclient

Password: sen382

Folder: /Outgoing/SEMAP Point V_1_10

NIF 3.0 ACCESS Database wi th the 8 NIF tables:

SEMAP 2007 Point NIF V_1_10a.zip

Annual point source files in SMOKE ORL form at are being prepared under SEMAP’s emission

modeling contract.

# Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc.

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# 1.12 REFERENCES

Dutch 2005. Steven Dutch, Natural and Applied Sciences, University of Wisconsin - Green Bay.

Converting UTM to Latitude and Longitude (Or Vice Versa) . Downloaded March 2009, last

updated 19 April 2005. http://www.uwgb.edu/dutchs/Us efulData/UTMFormulas.HTM

EPA 2004. U.S. Environment al Protection Agency. Basic Format and Content Checker. Version

Date 052604. 

# Software no longer available on EPA web site.

EPA 2005. U.S. Environment al Protection Agency. Emissions Inventory Guidance for

Implementation of Ozone and Pa rticulate Matter National Ambient Air Quality Standards

(NAAQS) and Regional Haze Regulations . EPA-454/R-05-001. August 2005.

http://www.epa.gov/ttn/chief/eidocs/ eiguid/eiguidf inal_nov2005.pdf

EPA 2006a. U.S. Environment al Protection Agency. NEI Quality Assurance and Data

Augmentation for Point Sources . February, 2006. .



# ftp://ftp.epa.gov/EmisInventory/2002finalnei/documentation/point/augmentation_point/20

02nei_qa_augmentation_report0206.pdf

EPA 2006b. U.S. Environment al Protection Agency. 2002 NEI Stack Parameter Default

. ftp://ftp.epa.gov/EmisInventory/ 2002finalnei/document ation/augmentati on_point_sector/

.

EPA 2007. U.S. Environment al Protection Agency. Guidance on the Use of Models and Other

Analyses for Demonstrating Attainment of Air Quality Goals for Ozone, PM 2.5 

# , and Regional

Haze. EPA -454/B-07-002. April 2007.



# http://www.epa.gov/ttn/scram/guidance/guide/final-03-pm-rh-guidance.pdf

EPA 2009a. U.S. Environment al Protection Agency. Clean Air Markets – Data and Maps Web Site;

Unit Level Emissions Query for 2007. File downloaded on October 8, 2009.



# http://camddataandmaps.epa.gov/gdm/index.cfm?fuseaction=emissions.wizard

EPA 2009b. U.S. Environment al Protection Agency. Clean Air Markets – Emissions Data in

SMOKE Format for 2007. File (hour_unit_2007.zip) downloaded on October 8, 2009.



# http://camddataandmaps.epa.gov/gdm/index.cfm ?fuseaction=emissions.prepacksmoke

EPA 2009c. U.S. Environment al Protection Agency. 2005 National Emissions Inventory Data &

Documentation . file name: 2005v4CAPHAP_orl_point.zip. June 2009.

ftp://ftp.epa.gov/EmisI nventory/2005v4/2005emis

MARAMA 2006. Mid-Atlantic Regi onal Air Management Association. Technical Support

Documentation for 2002 MANE-VU SIP M odeling Inventories, Version 3. November 20,

2006. 

# http://www.marama.org/technical-center/emissions-inventory/2002-inventory-andprojections/mane-vu-2002-emissions-inventory

SESARM 2009. Southeastern States Air Resource Managers, Inc. Point Source, On-Road, and

Fire Base Year, Future Year, and Control Strategy Emissions Inventories – Quality

Assurance Project Plan . August 2009.

VISTAS 2007. Visibility Impr ovement State and Tribal Asso ciation of the Southeast. Documentation

of the Base G 2002 Base Year, 2009, and 2018 Emission Inventories for the Visibility

Improvement State and Tribal A ssociation of the Southeast. February 2007.

http://www.vistas-sesarm.org/doc uments/VISTABF2003-20-2008.pdf

# Appendix A: Facilities with Updated Latitude and Longitude InformationDevelopment of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20111-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010070001Alabama Pigments Co001-87.12705933.226081010070001Alabama Pigments Co002-87.12705933.226081010070001Alabama Pigments Co888-87.12705933.226081010150088SOUTHERN HERITAGE CASKET COMPANY, INC.001-85.93089233.593406010430010American Proteins Inc002-86.80956733.956023010430010American Proteins Inc005-86.80956733.956023010430010American Proteins Inc006-86.80956733.956023010430010American Proteins Inc007-86.80956733.956023010430010American Proteins Inc010-86.80956733.956023010430010American Proteins Inc011-86.80956733.956023010430010American Proteins Inc888-86.80956733.95602301073010730078CLUTCH & BRAKE SPECIALTY CO., INC.002-86.78642533.51421301073010730167ERGON TERMINALLING, INC.004-87.10799333.56035901073010730339SHELBY CONCRETE, INC.001-86.81318133.36740401073010730503LAFARGE BUILDING MATERIALS, BIRMINGHAM PLANT001-86.81324733.571241010930014Glen Allen Rail Inc002-87.74853733.915734010930014Glen Allen Rail Inc888-87.74853733.915734010930023King Kutter Inc001-87.82036433.921496010950046Jackson Paving & Construction Company888-86.23292934.460514010970010ExxonMobil Production Company001-88.05220330.25394010970010ExxonMobil Production Company002-88.05220330.25394010970010ExxonMobil Production Company003-88.05220330.25394010970010ExxonMobil Production Company004-88.05220330.25394010970010ExxonMobil Production Company005-88.05220330.25394010970010ExxonMobil Production Company006-88.05220330.25394010970010ExxonMobil Production Company007-88.05220330.25394010970010ExxonMobil Production Company008-88.05220330.25394010970010ExxonMobil Production Company010-88.05220330.25394010970010ExxonMobil Production Company011-88.05220330.25394010970010ExxonMobil Production Company012-88.05220330.25394Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20112-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010970010ExxonMobil Production Company013-88.05220330.25394010970010ExxonMobil Production Company015-88.05220330.25394010970010ExxonMobil Production Company016-88.05220330.25394010970010ExxonMobil Production Company017-88.05220330.25394010970010ExxonMobil Production Company018-88.05220330.25394010970010ExxonMobil Production Company019-88.05220330.25394010970010ExxonMobil Production Company020-88.05220330.25394010970010ExxonMobil Production Company021-88.05220330.25394010970010ExxonMobil Production Company022-88.05220330.25394010970010ExxonMobil Production Company023-88.05220330.25394010970010ExxonMobil Production Company888-88.05220330.25394010970012ExxonMobil Production Company001-88.04476430.295978010970012ExxonMobil Production Company002-88.04476430.295978010970012ExxonMobil Production Company003-88.04476430.295978010970012ExxonMobil Production Company004-88.04476430.295978010970012ExxonMobil Production Company005-88.04476430.295978010970012ExxonMobil Production Company006-88.04476430.295978010970012ExxonMobil Production Company007-88.04476430.295978010970012ExxonMobil Production Company008-88.04476430.295978010970012ExxonMobil Production Company009-88.04476430.295978010970013ExxonMobil Production Company001-88.12485330.19192010970013ExxonMobil Production Company002-88.12485330.19192010970013ExxonMobil Production Company003-88.12485330.19192010970013ExxonMobil Production Company004-88.12485330.19192010970013ExxonMobil Production Company005-88.12485330.19192010970013ExxonMobil Production Company006-88.12485330.19192010970013ExxonMobil Production Company007-88.12485330.19192010970013ExxonMobil Production Company009-88.12485330.19192010970013ExxonMobil Production Company888-88.12485330.19192010970016Shell Exploration & Production Company001-88.07732330.178614Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20113-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010970016Shell Exploration & Production Company002-88.07732330.178614010970016Shell Exploration & Production Company004-88.07732330.178614010970016Shell Exploration & Production Company005-88.07732330.178614010970016Shell Exploration & Production Company006-88.07732330.178614010970016Shell Exploration & Production Company007-88.07732330.178614010970025ExxonMobil Production Company001-87.95254430.18879010970025ExxonMobil Production Company002-87.95254430.18879010970025ExxonMobil Production Company003-87.95254430.18879010970025ExxonMobil Production Company004-87.95254430.18879010970025ExxonMobil Production Company005-87.95254430.18879010970025ExxonMobil Production Company006-87.95254430.18879010970025ExxonMobil Production Company007-87.95254430.18879010970025ExxonMobil Production Company888-87.95254430.18879010970038Mobile Abrasives003-88.03173630.688664010970038Mobile Abrasives888-88.03173630.688664010972002Armstrong World Industries Inc001-88.0582630.66557010972002Armstrong World Industries Inc002-88.0582630.66557010972002Armstrong World Industries Inc003-88.0582630.66557010972002Armstrong World Industries Inc004-88.0582630.66557010972002Armstrong World Industries Inc005-88.0582630.66557010972002Armstrong World Industries Inc006-88.0582630.66557010972002Armstrong World Industries Inc007-88.0582630.66557010972002Armstrong World Industries Inc008-88.0582630.66557010972002Armstrong World Industries Inc009-88.0582630.66557010972002Armstrong World Industries Inc010-88.0582630.66557010972002Armstrong World Industries Inc011-88.0582630.66557010972002Armstrong World Industries Inc013-88.0582630.66557010972002Armstrong World Industries Inc014-88.0582630.66557010974019MoBay Storage Hub, Inc001-88.22553530.253211010974019MoBay Storage Hub, Inc002-88.22553530.253211Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20114-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010974019MoBay Storage Hub, Inc003-88.22553530.253211010976002Bender Shipbuilding & Repair Co Inc888-88.043630.684538010976007Alabama Shipyards Inc001-88.03259430.67713501099S011Owens Lumber Company001-86.98158631.795439011130018Boral Bricks001-84.99828732.458431011130018Boral Bricks002-84.99828732.458431011130018Boral Bricks003-84.99828732.458431011130018Boral Bricks005-84.99828732.458431011130018Boral Bricks006-84.99828732.458431011130018Boral Bricks007-84.99828732.458431011130018Boral Bricks888-84.99828732.458431011170005Alabama Power Company001-86.45989733.242746011170005Alabama Power Company002-86.4575833.244561011170005Alabama Power Company004-86.4575833.244561011170005Alabama Power Company888-86.45989733.242746011230015Stone's Throw Landfill888-85.83157932.511095011270015S&M Paving Co.001-87.60950433.958754120090090051NASA69-80.6518928.529149120310310010BAPTIST MEDICAL CENTER14-81.66374630.31471120310310213U S NAVAL STATION MAYPORT33-81.40639630.390052120310310213U S NAVAL STATION MAYPORT34-81.41753930.389417120310310213U S NAVAL STATION MAYPORT37-81.41753930.389417120310310325TRANSFLO TERMINAL SERVICES, INC.1-81.72005530.326385120450450002ARIZONA CHEMICALCOMPANY, LLC13-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC15-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC16-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC17-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC5-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC6-85.30833329.818056120570570094MOSAIC FERTILIZER, LLC100-82.4072927.80519Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20115-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat120570570252CEMEX2-82.43257427.901451120570570252CEMEX4-82.43257427.901451120690694822MIDDLESEX ASPHALT, L.L.C.2-81.90384828.832607120990990350SOUTH FLORIDA WATER MANAGEMENT DISTRICT1-80.44577826.472064121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA5-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA6-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA7-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA8-82.60166727.861389121091090022LUHRS CORPORATION1-81.32194429.879167121131130040ODOM FIBERGLASS, INCORPORATED1-87.08720430.5442811301501500011Ga Power Company - Plant BowenS1-84.919234.12561301501500011Ga Power Company - Plant BowenS2-84.919234.12561301501500011Ga Power Company - Plant BowenS3-84.919234.12561301501500011Ga Power Company - Plant BowenS4-84.919234.12561301501500011Ga Power Company - Plant BowenSCT1-84.919234.12561301501500011Ga Power Company - Plant BowenSCT2-84.919234.12561303903900003Naval Submarine BasePT01-81.5530630.80011303903900003Naval Submarine BasePT02-81.5530630.80011303903900003Naval Submarine BasePT03-81.5530630.80011303903900003Naval Submarine BasePT04-81.5530630.80011303903900003Naval Submarine BasePT05-81.5530630.80011303903900003Naval Submarine BasePT06-81.5530630.80011303903900003Naval Submarine BasePT07-81.5530630.80011303903900003Naval Submarine BasePT08-81.5530630.80011303903900003Naval Submarine BasePT09-81.5530630.80011303903900003Naval Submarine BasePT10-81.5530630.80011303903900003Naval Submarine BasePT11-81.5530630.80011303903900003Naval Submarine BasePT12-81.5530630.80011303903900003Naval Submarine BasePT13-81.5530630.80011303903900003Naval Submarine BasePT14-81.5530630.8001Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20116-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1303903900003Naval Submarine BasePT15-81.5530630.80011303903900003Naval Submarine BasePT16-81.5530630.80011304504500052Southwire Company Carrollton Utility Products PlantF722-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN11-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN12-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN13-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN15-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN16-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN17-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN18-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN2-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN3-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN4-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN5-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN6-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN7-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS205-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS280-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS281-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS296-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS297-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS501-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS504-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS507-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS510-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS513-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS516-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS721-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS745-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS760-85.06226833.566447Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20117-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1304504500052Southwire Company Carrollton Utility Products PlantS761-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS12-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS13-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS14-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS5-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS6-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS7-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS8-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS9-85.06226833.5664471304904900004West Fraser - Folkston Lumber MillFOB1-82.011830.849371304904900004West Fraser - Folkston Lumber MillFOB2-82.011830.849371305105100076Colonial Terminals, Inc.SB01-81.11210932.0941171305105100076Colonial Terminals, Inc.SB02-81.11210932.0941171305105100076Colonial Terminals, Inc.SB03-81.11210932.0941171305105100076Colonial Terminals, Inc.SD01-81.11210932.0941171305105100076Colonial Terminals, Inc.SD02-81.11210932.0941171305105100076Colonial Terminals, Inc.SD03-81.11210932.0941171305105100076Colonial Terminals, Inc.SD04-81.11210932.0941171305105100076Colonial Terminals, Inc.SD22-81.11210932.0941171305105100076Colonial Terminals, Inc.SD91-81.11210932.0941171305105100076Colonial Terminals, Inc.SM01-81.11210932.0941171305105100076Colonial Terminals, Inc.SR21-81.11210932.0941171305105100076Colonial Terminals, Inc.SR22-81.11210932.0941171305105100076Colonial Terminals, Inc.ST01-81.11210932.0941171305105100076Colonial Terminals, Inc.ST02-81.11210932.0941171305105100076Colonial Terminals, Inc.ST03-81.11210932.0941171305105100076Colonial Terminals, Inc.ST04-81.11210932.0941171305105100076Colonial Terminals, Inc.ST05-81.11210932.0941171305105100076Colonial Terminals, Inc.ST06-81.11210932.0941171305105100076Colonial Terminals, Inc.ST12-81.11210932.094117Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20118-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1305105100076Colonial Terminals, Inc.ST13-81.11210932.0941171305105100076Colonial Terminals, Inc.SVR4-81.11210932.0941171305105100076Colonial Terminals, Inc.SVR9-81.11210932.0941171305105100148ARIZONA CHEMICAL CORP.S1-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S10-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S11-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S12-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S13-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S14-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S2-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S3-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S4-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S5-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S6-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S7-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S8-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S9-81.1226232.0908031305105100152Savannah Resource Recovery (Montaney)ST01-81.0279132.079161305105100152Savannah Resource Recovery (Montaney)ST02-81.0279132.079161306306300059Delta Air Lines Inc - Atlanta StationFUG-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS1-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS2-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS3-84.413933.64331306506500005Bway Manufacturing IncS0-82.7738131.029071306506500005Bway Manufacturing IncS1-82.7738131.029071306506500005Bway Manufacturing IncS13-82.7738131.029071306506500005Bway Manufacturing IncS15-82.7738131.029071306506500005Bway Manufacturing IncS16-82.7738131.029071306506500005Bway Manufacturing IncS2-82.7738131.029071306506500005Bway Manufacturing IncS20-82.7738131.02907Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20119-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1306506500005Bway Manufacturing IncS3-82.7738131.029071306506500005Bway Manufacturing IncS9-82.7738131.029071306706700032Marathon Petroleum Company LLC - Powder Springs TerminalFUG-84.6304833.863021306706700032Marathon Petroleum Company LLC - Powder Springs TerminalVCS-84.6304833.863021307307300003Quebecor World Kri Inc.FUG-82.1179133.543361307307300003Quebecor World Kri Inc.S1-82.1179133.543361307307300003Quebecor World Kri Inc.S10-82.1179133.543361307307300003Quebecor World Kri Inc.S11-82.1179133.543361307307300003Quebecor World Kri Inc.S12-82.1179133.543361308108100054Norbord Georgia IncS001-83.8022231.966061308108100054Norbord Georgia IncS003-83.8022231.966061308108100054Norbord Georgia IncS004-83.8022231.966061308108100054Norbord Georgia IncS010-83.8022231.966061308108100054Norbord Georgia IncS011-83.8022231.966061308108100054Norbord Georgia IncS012-83.8022231.966061308108100054Norbord Georgia IncS013-83.8022231.966061308108100054Norbord Georgia IncS063-83.8022231.966061308908900085Magellan Terminal Holdings, L.P. - Doraville I TerminalFUG-84.26993433.915191308908900085Magellan Terminal Holdings, L.P. - Doraville I TerminalS1-84.26993433.915191308908900128Transmontaigne Terminaling IncCGLK-84.27396133.9168411308908900128Transmontaigne Terminaling IncFUG-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8501-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8502-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8504-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8505-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8506-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8507-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8509-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8510-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8515-84.27396133.916841Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201110-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1308908900128Transmontaigne Terminaling IncST8516-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTLOAD-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTVCU-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTVRU-84.27396133.9168411309509500010MillerCoors LLCF036-84.0880531.59331309509500010MillerCoors LLCS001-84.0880531.59331309509500010MillerCoors LLCS003-84.0880531.59331309509500010MillerCoors LLCS034-84.0880531.59331309909900001Georgia-Pacific Corp Cedar Springs OperationFUG-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationINSIG-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS1-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS10-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS11-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS12-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS13-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS14-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS15-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS16-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS17-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS18-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS19-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS2-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS20-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS21-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS22-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS23-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS24-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS25-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS26-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS27-85.09547431.167343Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201111-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1309909900001Georgia-Pacific Corp Cedar Springs OperationS28-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS29-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS3-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS5-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS6-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS7-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS8-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS9-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationVSTACK-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationWTS-85.09547431.1673431310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)FUG-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S1-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S10-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S11-81.2017832.331131310310300007Georgia-Pacific Consumer Products 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R. Chapman(01)-86.85737.90052109100026L. R. Chapman(02)-86.85737.90052109100026L. R. Chapman(03)-86.85737.90052109100026L. R. Chapman(04)-86.85737.90052109100026L. R. Chapman(05)-86.85737.90052109100026L. R. Chapman(06)-86.85737.90052109100026L. R. Chapman(07)-86.85737.90052109100026L. R. Chapman(08)-86.85737.90052109100026L. R. Chapman(09)-86.85737.90052109100026L. R. Chapman(10)-86.85737.90052109100026L. R. Chapman(11)-86.85737.90052109100026L. R. Chapman(12)-86.85737.90052109100026L. R. Chapman(13)-86.85737.90052109100026L. R. Chapman(14)-86.85737.90052109100026L. R. Chapman(15)-86.85737.90052109100026L. R. Chapman(16)-86.85737.90052109100026L. R. Chapman(17)-86.85737.90052109100026L. R. Chapman(18)-86.85737.90052109100026L. R. Chapman(19)-86.85737.90052109100026L. R. Chapman(20)-86.85737.90052109100026L. R. Chapman(21)-86.85737.90052109100026L. R. Chapman(22)-86.85737.90052109100026L. R. Chapman(23)-86.85737.90052109100026L. R. Chapman(24)-86.85737.9005Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201121-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2109100026L. R. Chapman(25)-86.85737.90052109100026L. R. Chapman(26)-86.85737.90052109100026L. R. Chapman(27)-86.85737.90052109100026L. R. Chapman(28)-86.85737.90052109100026L. R. Chapman(29)-86.85737.90052109100026L. R. Chapman(30)-86.85737.90052109100026L. R. Chapman(31)-86.85737.90052109100026L. R. Chapman(32)-86.85737.90052109100026L. R. Chapman(33)-86.85737.90052109100026L. R. Chapman(34)-86.85737.90052109100026L. R. Chapman(35)-86.85737.90052109100026L. R. Chapman(36)-86.85737.90052109100026L. R. Chapman(37)-86.85737.90052109100026L. R. Chapman(38)-86.85737.90052109100026L. R. Chapman(39)-86.85737.90052109100026L. R. Chapman(40)-86.85737.90052109100026L. R. Chapman(41)-86.85737.90052109100026L. R. Chapman(42)-86.85737.90052109100026L. R. Chapman(43)-86.85737.90052109100026L. R. Chapman(44)-86.85737.90052109100026L. R. Chapman(45)-86.85737.90052109100026L. R. Chapman(46)-86.85737.90052109100026L. R. Chapman(47)-86.85737.90052109100026L. R. Chapman(48)-86.85737.90052109100026L. R. Chapman(49)-86.85737.90052109100026L. R. Chapman(50)-86.85737.90052109100026L. R. Chapman(51)-86.85737.90052109100026L. R. Chapman(52)-86.85737.90052110100139Kentucky 5 Star Energy LLCFS01-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS02-87.5241537.6462Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201122-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2110100139Kentucky 5 Star Energy LLCFS03-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS04-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS05-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS06-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS07-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV01-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV02-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV03-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV04-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV05-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV06-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV07-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV08-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV09-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV10-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV11-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV12-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV13-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV1415-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV16-87.5241537.64622110100139Kentucky 5 Star Energy LLCTK1-5-87.5241537.64622110700146Hopkinsville Wood Products001-87.689437.16522110700146Hopkinsville Wood Products002-87.689437.16522110700156J-Lok CorpEP-AU--87.4873937.277492110700156J-Lok CorpEP-V-1-87.4873937.277492110700156J-Lok CorpEP-V-2-87.4873937.277492110700156J-Lok CorpEP-V-3-87.4873937.277492111700165Laser Graphic Systems001-84.62769939.0376142111700165Laser Graphic Systems002-84.62769939.0376142111700165Laser Graphic Systems003-84.62769939.037614Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201123-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2111700174BBS Tech IncEP1-84.623339.05392111700176Alstom Power IncEP1-84.630539.04522111700176Alstom Power IncEP2-84.630539.04522111900038Chesapeake Appalachia LLC - Brinkley Transmission Station001-82.944537.29452111900040Chesapeake Appalachia LLC - Lackey Transmission Station001-82.833137.46652111900041ICG Knott Co - Raven Coal Preperation PlantGroup1-82.82367337.4018752111900041ICG Knott Co - Raven Coal Preperation PlantGroup2-82.82367337.4018752111900041ICG Knott Co - Raven Coal Preperation PlantGroup3-82.82367337.4018752112100032Gatliff Coal Co - ADA Tipple 5001-83.8205636.840282112100032Gatliff Coal Co - ADA Tipple 5002-83.8205636.840282112100032Gatliff Coal Co - ADA Tipple 5003-83.8205636.840282112500084Admiralty Boats Inc001-84.073936.97252112500084Admiralty Boats Inc002-84.073936.97252112500084Admiralty Boats Inc003-84.073936.97252112500084Admiralty Boats Inc005-84.073936.97252112500084Admiralty Boats Inc006-84.073936.97252112500106ABC Automotive Systems IncEP1-21-84.0335237.21252112500106ABC Automotive Systems IncEP22-84.0335237.21252112500106ABC Automotive Systems IncEP23-84.0335237.21252112500106ABC Automotive Systems IncEP24-84.0335237.21252113300079Mountain Enterprises Inc - Cumberland Plant 200101-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200201-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200202-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200301-83.0211136.97862113500013Mountain Enterprises Inc -Vanceburg Plant 30001-83.347538.59232113500013Mountain Enterprises Inc -Vanceburg Plant 30002-83.347538.59232113500013Mountain Enterprises Inc -Vanceburg Plant 30003-83.347538.59232114100020Hanson Aggregates Midwest LLC - Rockfield Quarry001-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry002-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry003-86.614536.882Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201124-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2114100020Hanson Aggregates Midwest LLC - Rockfield Quarry004-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry005-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry006-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry007-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry008-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry009-86.614536.8822114100060Bowling Green Concrete - Rockfield Ready-Mix Plant001-86.614536.8822117900034Heaven Hill Distilleries Inc001-85.5607937.8981412118300069Western KY Energy Corp - Wilson StationEU-01-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-02-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-03-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-04-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-05-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationIA-87.07909637.4521042119500267EQT Gathering LLC - Rockhouse Compressor Station01-82.328137.53772119500267EQT Gathering LLC - Rockhouse Compressor Station02-82.328137.53772120700022Pyles Concrete Inc001-85.05916737.1061112120700022Pyles Concrete Inc002-85.05916737.1061112120700022Pyles Concrete Inc003-85.05916737.1061112121100050LG&E\KU System Control & Data Center1-85.349838.21172121100050LG&E\KU System Control & Data Center2-85.349838.21172121300029South Union Elevator001-86.655436.87512121300029South Union Elevator002-86.655436.87512121300029South Union Elevator003-86.655436.87512121300029South Union Elevator004-86.655436.87512121300029South Union Elevator005-86.655436.87512121700033TN Gas Pipeline - Station 96001-85.394437.41372121700033TN Gas Pipeline - Station 96FUG01-85.394437.41372121700035Ambrake Corp001-85.329437.34122121700035Ambrake Corp002-85.329437.3412Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201125-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2121700035Ambrake Corp003-85.329437.34122121900013Koppers Industries,Inc001-87.156436.64332121900013Koppers Industries,Inc002a-87.156436.64332121900013Koppers Industries,Inc002b-87.156436.64332121900013Koppers Industries,Inc003-87.156436.64332121900013Koppers Industries,Inc004-87.156436.64332121900013Koppers Industries,Inc005-87.156436.64332121900013Koppers Industries,Inc006-87.156436.64332123300008Webster Co Coal LLC - Dotiki Mine Prep Plant001-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant002-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant003-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant004-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant005-87.77468937.45402370210735Western Animal Disease Diagnostic LaboratoryES-1-82.53435.4294370573705700265CEMEX Construction Materials, Atlantic, LLCES2-80.047635.9019370573705700265CEMEX Construction Materials, Atlantic, LLCES3-80.047635.9019370573705700265CEMEX Construction Materials, Atlantic, LLCES4-80.047635.901937119134Rea Contracting, LLC. (069 Arrowood)1-80.920335.0928450030080-0011SCE&G URQUHART3-81.911433.4342450150420-0015ALUMAX OF SOUTH CAROLINA1-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA10-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA100-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA101-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA11-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA12-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA122-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA123-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA124-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA13-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA14-80.054233.0517Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201126-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat450150420-0015ALUMAX OF SOUTH CAROLINA15-80.054233.0517450150420-0015ALUMAX OF SOUTH 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Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201147-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat471490155NISSAN NORTH AMERICA, INC.SOB3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SOS3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SPP3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SPP4-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.TC1-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.TC23-86.49231433868435.9616818991803471490172STRATOS (JAVELIN_2 BOATS)65978-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)65979-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)65980-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)S-014-86.38252635.794599471530034TECUMSEH PRODUCTS CO.S-001-85.37884435.389409471530034TECUMSEH PRODUCTS CO.S-002-85.37884435.389409471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A01-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A02-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A03-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A04-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A05-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A06-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A07-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A08-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A09-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C01-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C02-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C03-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C04-86.557936.61539471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C05-86.557936.61539471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C06-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C07-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C08-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D01-86.55774436.615342Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201148-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D02-86.55774436.615342471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D03-86.55774436.615342471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787E01-86.5577536.615269471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787E02-86.5577536.615269471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-3-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-4-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-5-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONREECO1-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONREECO2-89.620235.6198945100100012A and N Electric Cooperative - Tangier Island1-75.9937.825100161414Old Dominion Electric Cooperative - UNIT 91-7637.845100161415Old Dominion Electric Cooperative - UNIT 101-7637.845100300099Virginia Industries for the Blind1-78.47303338.0216355101900001Rubatex International LLC1-79.510237.3355102711159Equitable Production Co-Hurricane2-82.1537.13385103100006Babcock & Wilcox Nuclear Operations Group Inc21-79.055337.40915106500001Dominion - Bremo Power Station1-78.287837.70895107500030INGENCO - Rockville Plant1-77.66400937.7018395108100001Emporia Foundry Incorporated1-77.53359636.6953455108100011Belding Hausman Inc - Weldon Mill1-77.55790636.6878855108100020Georgia Pacific Wood Products - Emporia - Plywood1-77.52469336.6964945108500042Bear Island Paper Company LLC17-77.43884737.8130925109500023HRSD - Williamsburg Sewage Treatment Plant1-76.62911637.2145785110100001Stone Container Enterprises dba Smurfit-Stone Cont1-76.805337.53925110100004West Point Veneer LLC1-76.80705237.5452465110100021Old Dominion Grain1-76.81518137.5508935110100023Augusta Wood Products LC - Sawmill1-76.83381937.5691655110100027West Point Chips Incorporated1-76.802837.53475112100006Alliant Techsystems Inc2-80.54111137.1805565112100091Thermasteel Corporation1-80.56611137.116667Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201149-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat5113300013Waller, R P Oil BP1-76.27937.83895115300002Dominion - Possum Point Power Station10-77.28083338.5383335115300011Prince William Hospital Corporation5-77.48501138.7675155115300021LOCKHEED MARTIN MANASSAS11-77.51838.7466155115300814BAE Systems1-77.49703338.7549955115300889Architect of the Capitol2-77.51321138.7466155116100011Adams Construction Co - Rockydale1-79.946837.21495116100015Double Envelope Company1-79.955737.3536115116500069Adams Construction Company1-78.74154638.7012345116500106Transprint USA Inc1-78.90004738.39155117900020FBI Academy1-77.29021538.5214165119100044Universal Fibers Inc.1-82.105536.66285119500089P M Terminals Inc -Buck Oil Co1-82.313336.90445151500038Wheelabrator Abrasives Incorporated21-79.5536437.343985152000018Strongwell Corporation/Bristol Division6-82.177236.59615162000011Franklin City - Electric Dept - Mechanic Street1-76.91976236.6764955164000002Turman Hardwood Flooring Inc.5-80.939736.64975165000007US Air Force Base Langley15-76.351737.08255165000011US Department of Veterans Affairs Medical Ctr1-76.331937.01445165000093Bethel Landfill (USA Waste of Virginia)1-76.42636237.0728565168300003Glen-Gery Corporation - Capitol Plant1-77.504938.74045168300090City of Manassas/VMEA1-77.50805638.7397225169000050Southern Finishing1-79.85464636.6902115170000013Northrop Grumman Shipbuilding Incorporated28-76.43553636.9862045170000071Kinder Morgan Bulk Terminals - Pier IX1-76.43272736.9745565171000009Ford Motor Company Norfolk Plant6-76.25286136.8314475171000068U S Gypsum Co1-76.28560736.8278335171000113J H Miles & Company Incorporated1-76.30551736.8586165171000249Lyon Shipyard, Incorporated - Brown Ave1-76.27216236.8431475171000251Lyon Shipyard Incorporated - Sealift Drydock1-76.26506936.840516Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201150-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat5174000037Fleet & Industrial Supply Center1-76.37501836.8835335176000098Kinder Morgan Southeast Terminals-Rchmd Terminal10-77.42680537.4566475176000399Spruance Genco LLC1-77.42680537.4566475176000489Motiva Enterprises LLC-Richmond Terminal1-77.44530537.4919475181000013US Navy - Joint Expeditionary Base - Little Creek1-76.146936.90585181000034HRSD Chesapeake-Elizabeth Sewage Treatment Plant1-76.16472136.90675540295402900001ARCELORMITTAL WEIRTON INC.107-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.108-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.109-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.111-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.112-80.602840.4219

# Appendix B: Comparison of Original EGU Emissions Prepared by AMEC (V_1_10) with

Emissions Prepared by WV DAQ (v_1_10a)Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20111-BAMECFacility NameStateCountyFIPSState FacilityIdentifierEmissionUnit IDProcessIDSCCPollutantCodev_1-10EmissionNumericValuev1-10aEmissionNumericValueAppalachian Power - JohnE Amos Plant54079 5407900006 001 1 10100202 PM10-PRI 393 1,164Appalachian Power - JohnE Amos Plant54079 5407900006 001 1 10100202 PM25-PRI 305 1,100Appalachian Power - JohnE Amos Plant54079 5407900006 002 1 10100202 PM10-PRI 427 1,280Appalachian Power - JohnE Amos Plant54079 5407900006 002 1 10100202 PM25-PRI 331 1,209Appalachian Power - JohnE Amos Plant54079 5407900006 003 1 10100202 PM10-PRI 871 1,989Appalachian Power - JohnE Amos Plant54079 5407900006 003 1 10100202 PM25-PRI 676 1,845Appalachian Power -Kanawha River Plant54039 5403900006 001 1 10100202 PM10-PRI 104 327Appalachian Power -Kanawha River Plant54039 5403900006 001 1 10100202 PM25-PRI 80 280Appalachian Power -Kanawha River Plant54039 5403900006 002 1 10100202 PM10-PRI 115 362Appalachian Power -Kanawha River Plant54039 5403900006 002 1 10100202 PM25-PRI 89 309Appalachian Power -Mountaineer Plant54053 5405300009 001 1 10100202 PM10-PRI 609 1,660Appalachian Power -Mountaineer Plant54053 5405300009 001 1 10100202 PM25-PRI 473 1,506Appalachian Power Co.-Philip Sporn Plant54053 5405300001 001 1 10100202 PM10-PRI 148 351Appalachian Power Co.-Philip Sporn Plant54053 5405300001 001 1 10100202 PM25-PRI 115 332Appalachian Power Co.-Philip Sporn Plant54053 5405300001 002 1 10100202 PM10-PRI 108 269Appalachian Power Co.-Philip Sporn Plant54053 5405300001 002 1 10100202 PM25-PRI 84 255Appalachian Power Co.-Philip Sporn Plant54053 5405300001 003 1 10100202 PM10-PRI 148 360Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20112-BAMECFacility NameStateCountyFIPSState FacilityIdentifierEmissionUnit IDProcessIDSCCPollutantCodev_1-10EmissionNumericValuev1-10aEmissionNumericValueAppalachian Power Co.-Philip Sporn Plant54053 5405300001 003 1 10100202 PM25-PRI 115 341Appalachian Power Co.-Philip Sporn Plant54053 5405300001 004 1 10100202 PM10-PRI 155 377Appalachian Power Co.-Philip Sporn Plant54053 5405300001 004 1 10100202 PM25-PRI 120 357Appalachian Power Co.-Philip Sporn Plant54053 5405300001 005 1 10100202 PM10-PRI 373 818Appalachian Power Co.-Philip Sporn Plant54053 5405300001 005 1 10100202 PM25-PRI 289 773Monongahela Power Co -Albright P.S.54077 5407700001 001 1 10100202 PM10-PRI 7 281Monongahela Power Co -Albright P.S.54077 5407700001 001 1 10100202 PM25-PRI 4 273Monongahela Power Co -Albright P.S.54077 5407700001 002 1 10100202 PM10-PRI 11 280Monongahela Power Co -Albright P.S.54077 5407700001 002 1 10100202 PM25-PRI 6 273Monongahela Power Co -Albright P.S.54077 5407700001 003 1 10100212 PM10-PRI 0 609Monongahela Power Co -Albright P.S.54077 5407700001 003 1 10100212 PM25-PRI 0 567Monongahela Power Co. -Rivesville Ps54049 5404900009 001 1 10100202 PM10-PRI 1 4Monongahela Power Co. -Rivesville Ps54049 5404900009 001 1 10100202 PM25-PRI 1 4Monongahela Power Co. -Rivesville Ps54049 5404900009 002 1 10100202 PM10-PRI 32 166Monongahela Power Co. -Rivesville Ps54049 5404900009 002 1 10100202 PM25-PRI 19 137Monongahela Power Co.-Fort Martin Power54061 5406100001 001 1 10100212 PM10-PRI 110 2,196Monongahela Power Co.-Fort Martin Power54061 5406100001 001 1 10100212 PM25-PRI 65 2,164Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20113-BAMECFacility NameStateCountyFIPSState FacilityIdentifierEmissionUnit IDProcessIDSCCPollutantCodev_1-10EmissionNumericValuev1-10aEmissionNumericValueMonongahela Power Co.-Fort Martin Power54061 5406100001 002 1 10100202 PM10-PRI 66 2,254Monongahela Power Co.-Fort Martin Power54061 5406100001 002 1 10100202 PM25-PRI 39 2,219Monongahela Power Co.-Willow Island54073 5407300004 001 1 10100202 PM10-PRI 2 135Monongahela Power Co.-Willow Island54073 5407300004 001 1 10100202 PM25-PRI 1 117Monongahela Power Co.-Willow Island54073 5407300004 002 1 10100203 PM10-PRI 236 368Monongahela Power Co.-Willow Island54073 5407300004 002 1 10100203 PM25-PRI 211 337Monongahela Power CoHarrison54033 5403300015 001 1 10100202 PM10-PRI 603 943Monongahela Power CoHarrison54033 5403300015 001 1 10100202 PM25-PRI 480 644Monongahela Power CoHarrison54033 5403300015 002 1 10100202 PM10-PRI 506 859Monongahela Power CoHarrison54033 5403300015 002 1 10100202 PM25-PRI 403 583Monongahela Power CoHarrison54033 5403300015 003 1 10100202 PM10-PRI 632 1,060Monongahela Power CoHarrison54033 5403300015 003 1 10100202 PM25-PRI 503 723Monongahela Power CoPleasants Power Sta54073 5407300005 001 1 10100202 PM10-PRI 584 465Monongahela Power CoPleasants Power Sta54073 5407300005 001 1 10100202 PM25-PRI 314 395Monongahela Power CoPleasants Power Sta54073 5407300005 002 1 10100202 PM10-PRI 258 490Monongahela Power CoPleasants Power Sta54073 5407300005 002 1 10100202 PM25-PRI 139 414Mount Storm Power Station 54023 5402300003 001 1 10100212 PM10-PRI 92 2,388Mount Storm Power Station 54023 5402300003 001 1 10100212 PM25-PRI 73 2,355Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20114-BAMECFacility NameStateCountyFIPSState FacilityIdentifierEmissionUnit IDProcessIDSCCPollutantCodev_1-10EmissionNumericValuev1-10aEmissionNumericValueMount Storm Power Station 54023 5402300003 002 1 10100212 PM10-PRI 97 2,488Mount Storm Power Station 54023 5402300003 002 1 10100212 PM25-PRI 77 2,454Mount Storm Power Station 54023 5402300003 003 1 10100212 PM10-PRI 191 510Mount Storm Power Station 54023 5402300003 003 1 10100212 PM25-PRI 151 397North Branch PowerStation54023 5402300014 001 1 10100217 PM10-PRI 19 55North Branch PowerStation54023 5402300014 001 1 10100217 PM25-PRI 3 55North Branch PowerStation54023 5402300014 002 1 10100217 PM10-PRI 18 34North Branch PowerStation54023 5402300014 002 1 10100217 PM25-PRI 3 34Ohio Power - KammerPlant54051 5405100006 001 1 10100203 PM10-PRI 34 760Ohio Power - KammerPlant54051 5405100006 001 1 10100203 PM25-PRI 28 754Ohio Power - KammerPlant54051 5405100006 002 1 10100203 PM10-PRI 33 726Ohio Power - KammerPlant54051 5405100006 002 1 10100203 PM25-PRI 27 720Ohio Power - KammerPlant54051 5405100006 003 1 10100203 PM10-PRI 34 755Ohio Power - KammerPlant54051 5405100006 003 1 10100203 PM25-PRI 28 750Ohio Power - Mitchell Plant 54051 5405100005 001 1 10100202 PM10-PRI 244 1,112Ohio Power - Mitchell Plant 54051 5405100005 001 1 10100202 PM25-PRI 189 1,056Ohio Power - Mitchell Plant 54051 5405100005 002 1 10100202 PM10-PRI 331 1,416Ohio Power - Mitchell Plant 54051 5405100005 002 1 10100202 PM25-PRI 257 1,345Notes:v_1_10 values based on PM augmentation by AMEC of PM filterabledata provided by WV DAQv_1_10a values calculated from emissionfactors based on the ratio of NEI 2002emissions to CAMD 2002 heat inputs. Those factors were applied to 2007 CAMD heat inputs.At the time WV DAQ requested that its data replace the original AMEC data, DAQ believed that the same methodology was necessary between its 2008 NEI submittal and the2007 SEMAP inventory. That belief later turned out to be incorrect. Therefore, the SEMAP 2007 inventory that was modeled reflectsdifferent methodology for WV EGUs than wasused for the other SEMAP states.

# A REA AND 

# N ONROAD 

# 2007 B ASE 

# Y EAR 

# I NVENTORIES



# R EVISED 

# F INAL 

# R EPORT

Contract No. S-2009-06-01

January 2012

Prepared for:

Ronald C. Methier

Southeastern States Air Resource Managers, Inc.

526 Forest Parkway, Suite F

Forest Park, GA 30297-6140

Prepared by:

TranSystems Corporation

3622 Lyckan Parkway, Suite 2005

Durham, NC 27707

# [This page intentionally left blank.]

# January 2012

Final Report 

# iii 

# CONTENTS

Page

TABLES ............................................

................................................... ................................................... ...................... iv

FIGURES ............................................

................................................... ................................................... .................... iv

I. INTRODUCTION ........................................

................................................... ................................................... .... 1

II. STATIONARY AREA SOURCE INVENTORY ....................

................................................... ............................... 3

A. AGENCY SUPPLIED INVENTORY DATA ....................

................................................... ........................... 3

B. DEVELOPMENT OF TRANSYSTEMS DEFAULT 2007 AREA SOURCE INVE NTORY ............................ 5

1. 2008 Nonpoint Source NEI ..........................

................................................... ................................. 5

a. Adjustment of NEI Data to Reflect 2007 Activity Lev els ............................................... ................ 11

b. Adjustment of NEI Data to Remove Activity Reflected in the Point Source Inventory .................. 1 1

2. Estimation of Area Source Emissions from Industrial and Commercial/Institutional Fuel

Combustion .......................................

................................................... ......................................... 16

a. Total ICI Energy Consumption .......................

................................................... ........................... 18

b. Stationary Source Energy Consumption ..............

................................................... ..................... 18

c. Non-Fuel Energy Consumption ........................

................................................... ......................... 22

d. Emission Factors ...................................

................................................... ................................... 23

e. Coal Sulfur and Ash Content .......................

................................................... ............................. 25

f. County Allocation Data ............................

................................................... ................................. 27

3. Estimation of Area Source Emissions from Residentia l Wood Combustion ................................. . 29

4. Estimation of Area Source Emissions from Gasoline S ervice Stations/Stage I ........................... .. 34

C. INVENTORY SUPPLEMENTATION/FINAL DATA MERGING .........

................................................... ..... 34

D. QA/QC PROCEDURES ..................................

................................................... ....................................... 39

III. 2007 NONROAD MOBILE SOURCE INVENTORY ..........

................................................... ................................... 40

A. NONROAD MODEL CATEGORIES ...........................

................................................... ............................ 40

B. AIRCRAFT ...........................................

................................................... .................................................. 42

C. COMMERCIAL MARINE VESSELS .........................

................................................... .............................. 43

D. LOCOMOTIVES ........................................

................................................... ............................................. 47

E. QA/QC PROCEDURES ..................................

................................................... ....................................... 48

IV. EMISSIONS SUMMARIES ...............................

................................................... ............................................... 51

A. STATIONARY AREA SOURCE EMISSIONS ...................

................................................... ..................... 51

B. NONROAD MOBILE SOURCE EMISSIONS ...................

................................................... ...................... 56

V. REFERENCES .........................................

................................................... ................................................... .... 61

APPENDIX A. POINT SOURCE SUBTRACTION PROCEDURE DETAILS ........... ............................................ A-1

# January 2012

Final Report 

# iv 

# TABLES

Table II-1. Overview of Area Source Inventory Compo nents by State/Local Agency ....................... ............................ 4

Table II-2. 2008 NEI Area Source Categories for Whi ch EPA Has Developed Emission Estimates ........... .................. 6

Table II-3. Methods for Updating 2008 NEI Estimates that Are Not Based on 2007 Emissions Activity .... ................. 12

Table II-4. Throughput-Based Area Source Emission Ad justments ......................................... ................................... 16

Table II.5. ICI Fuel Combustion Area Source Classifi cation Codes ...................................... ...................................... 17

Table II-6. LPG Nonroad Mobile Source Classificatio n Codes ........................................... ......................................... 19

Table II-7. Assumptions Used to Estimate Industrial Sector Stationary Source Distillate Fuel Consumptio n ............. 22

Table II-8. Assumptions Used to Estimate Commercial /Institutional Sector Stationary Source

Distillate Fuel Consumption ........................

................................................... ................................................... ........... 22

Table II-9. Industrial Sector Energy Consumption fr om Non-Fuel Uses.................................... .................................. 23

Table II-10. Criteria Pollutant Emission Factors for ICI Combustion Area Source Categories ............ ........................ 24

Table II-11. Bituminous/Subbituminous Coal Sulfur C ontent for 2007 ICI Combustion .................... .......................... 26

Table II-12. Anthracite Coal Ash and Sulfur Content for 2007 ICI Combustion .......................... ................................. 26

Table II-13. Summary of Data Carried Forward/Grown Fr om 2002 NEI ....................................... .............................. 36

Table II-14. Area Source Inventory Data Source Code s ................................................. ............................................ 39

Table III-1. Summary of 2007 NCD Tables and State Co mments............................................. .................................. 41

Table III-2. Aircraft Source Classification Codes .

................................................... ................................................... .. 42

Table III-3. Summary of State Updates to Aircraft C ategory Emissions ................................. ..................................... 43

Table III-4. Category 1 & CMV Growth Factors, by Pol lutant ............................................ .......................................... 44

Table III-5. Category 3 CMV Growth Factors, by State and SCC .......................................... ..................................... 45

Table III-6. Summary of State Updates to Commercial Marine Category Emissions ........................ .......................... 46

Table III-7. Summary of State Updates to Locomotive Category Emissions ............................... ................................ 49

Table III-8. Data Source Codes Used for Final 2007 N onroad Mobile Emission Estimates .................. ...................... 50

Table IV-1. Final 2007 SESARM Area Source Emissions by Major Sector ................................... ............................. 51

Table IV-2. Final 2007 Area Source Emission Estimate s by State ........................................ ..................................... 52

Table IV-3. Final 2007 Combustion Emission Estimates by State ......................................... ..................................... 53

Table IV-4. Final 2007 Solvent Emission Estimates by State ............................................ ......................................... 54

Table IV-5. Final 2007 Fugitive Dust Emission Estimat es by State ....................................... ..................................... 55

Table IV-6. Final 2007 All Other Area Source Emissio n Estimates by State............................... ................................ 56

Table IV-7. Final 2007 SESARM Nonroad Source Emissio ns by Major Sector ................................ .......................... 57

Table IV-8. Final 2007 NONROAD Model Emission Estima tes by State ...................................... .............................. 57

Table IV-9. Final 2007 Aircraft Emission Estimates b y State ........................................... ........................................... 58

Table IV-10. Final 2007 Commercial Marine Vessel Emi ssion Estimates by State .......................... ........................... 59

Table IV-11. Final 2007 Locomotive Emission Estimate s by State ........................................ ..................................... 60

Table A-1. Industrial Fuel Combustion Crosswalk for Point Source Subtractions. ....................... ............................. A-3

Table A-2. Commercial/Institutional Fuel Combustion Crosswalk for Point Source Subtractions .......... ................. A-12

Table A-3. Construction Crosswalk for Point Source Subtractions ...................................... ................................... A-15

Table A-4. Publicly Owned Treatment Works Crosswalk for Point Source Subtractions ..................... ................... A-16

Table A-5. Solvent Utilization Crosswalk for Point Source Subtractions ............................... .................................. A-17

Table A-6. Gasoline Distribution Crosswalk for Poin t Source Subtractions ............................. ............................... A-32

Table A-7. Mining and Quarrying Crosswalk for Point Source Subtraction ............................... .............................. A-38

Table A-8. Agriculture Production Crosswalk for Liv estock ............................................ ......................................... A-41



# FIGURES

Figure 1. Decision Tree for Assigning Regional Avera ge (Default) or National Urban Appliance Profile .. .................. 31

Figure 2. Decision Tree for Assigning Average (Defau lt), Urban, or Rural Burn Profiles ................ ............................ 33

# January 2012

Final Report 

# 1 

# I. INTRODUCTION

TranSystems is supporting the Southeastern States Ai r Resource Managers, Inc. (SESARM) in the Southeast ern

Modeling, Analysis, and Planning (SEMAP) project th at is funded by the same ten states originally invo lved in the

Visibility Improvement – State and Tribal Associatio n of the Southeast (VISTAS) project. The SEMAP pro ject

addresses the next phase of ozone, fine particle, a nd regional haze assessment obligations of the SESA RM member

states. The SEMAP project is designed to produce te chnical analyses to aid the participating agencies in developing

State Implementation Plans (SIPs) required by the C lean Air Act.

In June 2010, TranSystems developed a set of “final” 2007 area and nonroad source base year inventory e mission

estimates (Pechan, 2010). These estimates are repor ted by county and source classification code (SCC), and were

developed using data from a number of sources:

• State/Local (S/L) agency emissions data;

• 2007 year emissions data compiled from running EPA’ s NONROAD model with a combination of EPA

default and S/L agency-supplied inputs;

• 2007 area source emissions estimated by TranSystems, generally developed using the emissions

estimation procedures used to prepare EPA’s draft 2 008 National Emissions Inventory (NEI); 1



# • 2007 industrial and commercial/institutional (ICI) fuel combustion emission estimates developed by

TranSystems;

• 2008 commercial marine vessel and aircraft emission estimates from EPA’s draft 2008 NEI, modified by

TranSystems to reflect 2007 activity levels;

• 2007 switchyard and Class I line-haul locomotive es timates provided by the Eastern Regional Technical

Advisory Committee (ERTAC); and

• 2008 ERTAC Class II/III line-haul locomotive emissi on estimates, modified by TranSystems to reflect 200 7

activity levels.

Because EPA had not developed draft 2008 NEI emissi on estimates for Agricultural Tilling, Mining and Q uarrying,

and Pesticide Application at the time that the fina l area/nonroad source inventory was prepared, the f inal area source

inventory also incorporated guidance from S/L agenc ies as to whether to incorporate emission estimates carried

forward or grown 2 

# from EPA’s 2002 area source NEI for these source c ategories. For ICI fuel combustion and other

NEI source categories for which draft emission esti mates reflected total emissions activity, it was ne cessary for

TranSystems to perform point source subtractions to develop estimates of the emissions from area source s. These

point source subtractions were performed using vers ion 1.3 of the 2007 SEMAP point source inventory.

Since the final area source inventory was prepared in June 2010, SESARM requested that TranSystems inco rporate

additional S/L agency feedback into a revised final area source inventory. This feedback included dire ction to use

updated agency emissions data, and to revise/remove other emission estimates. In the latter case, fee dback

included direction to replace S/L agency estimates with TranSystems defaults, and to remove emission es timates for

specific fire source categories: Open Burning of L and Clearing Debris; Agricultural Field Burning; For est Wildfire;

and Prescribed Burning (these source categories are covered by a separate fire inventory developed by a different

SESARM contractor). 3 

# For two source categories, Residential Wood Combus tion and Stage I Gasoline Service

Stations, SESARM directed TranSystems to develop new emission estimates reflecting changes to some of t he

inputs that had been used to develop the 2008 area source NEI emission estimates. In addition, SESARM directed

1 

# 2008 NEI methods rely on Eastern Regional Technical Advisory Committee (ERTAC) methods when available.

2 

# Based on direction from S/L agencies, some 2002 NE I emission estimates were projected to 2007 using e mission activity

growth factors from Version 5.0 of the Economic Gro wth Analysis System (EGAS) (EPA, 2010).

3 

# In the case of Open Burning of Land Clearing Debris and Agricultural Field Burning, TranSystems provid ed the contractor

(AMEC) with a file containing the final area source inventory’s emission estimates.

# January 2012

Final Report 

# 2 

# TranSystems to re-perform the point source subtracti ons using an updated version (1.10a) of the SEMAP 2 007 point

source inventory. 4, 5



# Changes to the final nonroad mobile source inventor y were relatively modest, with the only major chang e relating to

the development of updated NONROAD model emission e stimates for Virginia using a new set of Reid vapor

pressure (RVP) values provided by the State.

The following sections provide additional details on the inventory development process. The major topi cs that are

discussed are:

• How TranSystems identified source categories and/or pollutants that may have been missing from the S/L

agency supplied data;

• How TranSystems integrated data from the various emi ssion data sources (i.e., S/L agencies, TranSystems

defaults, ERTAC, and 2008 and 2002 NEI); and

• How TranSystems quality assured the integrated emiss ions inventory.

The balance of this report is organized as follows. Section II describes the development of the statio nary area source

sector inventory. The development of the nonroad mo bile source sector inventory is described in Sectio n III.

Section IV presents the area and nonroad source emi ssion summaries for the final 2007 base year invent ory for the

SEMAP project. Section V presents the references t hat were consulted in preparing the revised final i nventory.

4 

# As requested, TranSystems performed the point sourc e subtractions for Georgia at the State-level (per Georgia’s earlier

direction, the final inventory had performed these subtractions at the county-level).

5 

# It should be noted that although EPA recently devel oped emissions estimates for Agricultural Tilling, Mining and Quarrying, and

Pesticide Application, and also incorporated revisi ons to the draft NEI emission estimates for Open Bu rning of Household Waste

(2610030000) and Yard Waste (2610000100 and 2610000 400), and Fugitive Dust from Paved Roads (229400000 0), SESARM

elected not to incorporate these updates into the r evised final area source inventory.

# January 2012

Final Report 

# 3 

# II. STATIONARY AREA SOURCE INVENTORY

TranSystems developed the revised final 2007 base ye ar area source inventory for the SEMAP project from a

combination of six sources:

1) S/L agency supplied area source emissions data;

2) TranSystems 2007 area source emission estimates deve loped using the emission estimation methods from

the 2008 NEI with adjustments to reflect 2007 emiss ions activity and to subtract point source emission s;

3) TranSystems 2007 industrial and commercial/instituti onal fuel combustion area source emission estimates

specifically developed for the SESARM states;

4) TranSystems 2007 emission estimates for gasoline ser vice stations/stage I unloading;

5) TranSystems 2007 emission estimates using EPA’s resi dential wood combustion tool with SESARMidentified modifications, and

6) Area source emission estimates carried forward or g rown from EPA’s 2002 nonpoint source NEI.

Table II-1 summarizes how these data sources were me rged to create a comprehensive stationary area sour ce

inventory for jurisdictions covered by the SEMAP pr oject. The following sections provide more specifi cs on the

contents of each of these data sources and how they were combined into the final 2007 area source inve ntory.



# A. AGENCY SUPPLIED INVENTORY DATA

TranSystems commenced area source inventory developm ent work by providing S/L agencies with a Technical

Memorandum documenting the emission estimation meth ods and data TranSystems was using to develop the U. S.

Environmental Protection Agency (EPA)’s 2008 nonpoi nt source NEI (Pechan, 2009a). The purpose of this

memorandum was to provide agencies with information to: (1) review and comment on the methods/data, a nd

(2) assist agencies in evaluating the merits of the NEI methods/data relative to any S/L area source i nventory

development efforts. State and local agencies were then provided with several months to compile and t ransmit area

source emissions data to TranSystems.

Two state agencies (North Carolina and Virginia) and two local agencies (Jefferson County, Kentucky and Davidson

County, Tennessee) provided area source data for the draft area source inventory (two additional local agencies

provided data for the final area source inventory – Knox County and Shelby County, Tennessee). After r eceiving

these S/L agency data, TranSystems compared the sour ce classification code (SCC) and pollutant coverage of these

submittals against the SCCs/pollutants in the 2007 emissions data that TranSystems was developing for t his project

(hereafter referred to as the “TranSystems default inventory”).

To assist in obtaining direction from SESARM agencie s on how to merge the data from these sources, TranS ystems

first identified the SCC/pollutant combinations in the TranSystems default inventory that matched to S/ L agency data.

Next, TranSystems reviewed remaining S/L agency SCC/ pollutant combinations against TranSystems defaults to

identify whether it may be possible that these emis sions were covered in the TranSystems default invent ory under

different SCCs. TranSystems then developed a list o f potential indirect matches between the two data s ets for

agency review. This list was compiled in an Excel w orksheet. Next, TranSystems developed a separate wo rksheet

that listed SCC/pollutant combinations in the S/L s upplied area source inventory that we were unable t o either directly

or indirectly match to combinations in the TranSyste ms default inventory. A list of SCC/pollutant comb inations in the

TranSystems default inventory that we were unable to directly or indirectly match to combinations in th e S/L agency

inventory was also prepared in a separate worksheet . Finally, TranSystems developed a worksheet that co ntained

all S/L agency inventory SCC/pollutant combinations with emissions equal to “0.” The above worksheets were saved

in a single Excel workbook for each Agency. In add ition to these workbooks, TranSystems transmitted a Word

document identifying questions on how two merge the two data sets (e.g., where S/L agency emissions ar e reported

as zero, should TranSystems replace any of these wit h emissions from the TranSystems default inventory?) . AfterJanuary 2012Final Report4Table II-1. Overview of Area Source Inventory Components by State/Local AgencyAlabamaFloridaGeorgiaKentuckyJeffersonCountyKentuckyRest of StateMississippiNorthCarolinaSouthCarolinaTennesseeDavidsonCountyTennesseeKnox CountyTennesseeShelbyCountyTennesseeRest of StateVirginiaWest VirginiaAgencyContactLisaCole/TracyAndersonKelly StevensByeong Kim Craig Butler Martin LutherElliottBickerstaffPhyllis JonesCarlaBedenbaughJohn FinkeSteveMcDanielChris Boyd Amanda DavisThomasFosterBob BettertonSourceofEmissionsDataCombinationof Agency dataandTranSystemsdefaults,supplementedwith categoriesfrom 2002 NEIgrown usingEGASTranSystemsdefaults,supplementedwith categoriesfrom 2002 NEI(combinationof EGAS andcarry forward)TranSystemsdefaults,supplementedwithcategoriesfrom 2005 GAConsolidatedEmissionsReportingRule (CERR)submittalgrown usingEGASCombination ofAgency dataandTranSystemsdefaults.TranSystemsdefaults,supplementedwith categoriesfrom 2002 NEIgrown usingEGASTranSystemsdefaults,supplementedwith categoriesfrom 2002 NEI(combinationof EGAS andcarry forward)Combinationof Agencydata andTranSystemsdefaults.TranSystemsdefaults,supplementedwithcategoriesfrom 2002 NEIgrown usingEGASCombinationof Agencydata andTranSystemsdefaults.Combinationof Agencydata andTranSystemsdefaults,supplementedwithcategoriesfrom 2002 NEI(emissionscarriedforward)AgencydataCombination ofAgency dataandTranSystemsdefaults,supplementedwith categoriesfrom 2002 NEI(emissionscarried forward)Combinationof Agencydata andTranSystemsdefaults,supplementedwithcategoriesfrom 2002 NEI(emissionscarriedforward)Combinationof Agencydata (Miningand Quarryingonly) andTranSystemsdefaults,supplementedwithcategoriesfrom 2002 NEI(emissionscarriedforward)

# January 2012

Final Report 

# 5 

# reviewing S/L agency responses to these questions, TranSystems transmitted any follow-up questions that were

necessary to clarify S/L agency guidance.



# B. DEVELOPMENT OF TRANSYSTEMS DEFAULT 2007 AREA SOURCE INVE NTORY

TranSystems created a default 2007 area source inven tory that included all of the source categories cov ered by the

2008 nonpoint source NEI as of early 2010. For all these source categories except industrial and

commercial/institutional (ICI) fuel combustion, sta ge I gasoline service stations, and residential woo d combustion,

TranSystems either directly incorporated emissions d ata from the 2008 nonpoint source NEI (when the NEI

represented use of 2007 emissions activity data), o r recalculated the NEI emission estimates to reflec t 2007 activity

levels (when the NEI reflected 2006 or 2008 activit y levels) and/or removed the emissions associated w ith activity

reflected in the point source inventory. As of ear ly 2010, the 2008 nonpoint source NEI had only deve loped ICI fuel

combustion emissions activity estimates, not emissi on estimates. Because of their potential importanc e and the

availability of methodological improvements, TranSys tems utilized an emissions estimation method for IC I fuel

combustion that incorporated a few refinements to t he NEI method. For stage I gasoline service station s, we

developed emission estimates for this project using the NEI methods in combination with inputs reviewe d and

approved by S/L agencies. For residential wood comb ustion (RWC), TranSystems updated the emission estim ates

by running EPA’s RWC emissions estimation tool with updates to the tool’s wood consumption and wood-bu rning

appliance profile/allocation assumptions. The follo wing section discusses how information from the 200 8 nonpoint

source NEI was used in this project. The subsequent sections provide details on the methods used to es timate

emissions from ICI fuel combustion, stage I gasolin e service stations, and residential wood combustion

.

1. 2008 Nonpoint Source NEI

TranSystems supported EPA efforts to develop the 200 8 nonpoint source NEI. Because of data availabilit y issues,

the 2008 NEI is comprised of data of various vintag es (2006-2008). Table II-2 provides documentation o f the 2008

nonpoint source NEI, which is as follows:

(1) Source Category – identifies the name of each gener al source category covered.

(2) Source Classification Code(s) – lists the SCCs that are inventoried.

(3) Source Classification Code Description – provides a description of each SCC.

(4) Link to Emission Calculation Documentation – provid es links to the detailed documentation of the NEI

methods; 6



# (5) Link to Emission Calculation Workbook – provides a link to the draft 2008 NEI emissions or activity da ta;

(6) Year of Activity Data – identifies the year represe nted by the emissions activity data; and

(7) Point Source Component – signifies whether a portio n of the source category’s emissions may be include d

within the point source inventory.

When work commenced on the revised final base year inventory in late 2011, TranSystems notified SESARM of the

availability of 2008 NEI emission estimates for the following additional area source categories: Agri cultural Tilling,

Mining and Quarrying, and Pesticide Application. S ESARM directed TranSystems not to incorporate the 20 08 NEI

emission estimates for these categories. In lieu o f such updates, the SEMAP emission estimates for th ese source

categories reflect direction from S/L agencies as t o whether to incorporate estimates based on emissio ns reported in

the 2002 NEI. In such cases where these categories were identified for inclusion, agencies also provi ded direction

as to whether the 2002 NEI emissions should be carr ied forward to represent 2007 emissions, or project ed to 2007

using growth factors from the Economic Growth Analy sis Systems (EGAS).

6 

# Left clicking on the hyperlink while simultaneously pressing the control key allows one to open or sav e the documentation/data

of interest. The complete list of material can be accessed at: http://projects.pechan.com/EPA/Non-Point_Emission_E stimates/

. Note that in some cases, this documentation reflect s revisions that EPA incorporated after the NEI dat a were compiled for this

project: SESARM opted not to incorporate NEI revis ions for Open Burning of Household Waste (261003000 0) and Yard Waste

(2610000100 and 2610000400), and Fugitive Dust from Paved Roads (2294000000).January 2012Final Report6Table II-2. 2008 NEI Area Source Categories for Which EPA Has Developed Emission EstimatesSource CategorySource ClassificationCode(s)Source Classification CodeDescriptionLink to Emission CalculationDocumentationLink to Emission CalculationWorkbookYear ofActivityDataPoint SourceComponentAgriculture Production–Livestock28050nnnnnLivestockAgriculture_Production_Livestock_28050nnnnn_Documentation.zipAgriculture_Production_Livestock_28050nnnnn_Emissions.zip2007Yes(selectedSCCs)Asphalt Paving2461021000Cutback AsphaltAsphalt_Paving_Cutback_2461021000_Documentation.zipAsphalt_Paving_Cutback_2461021000_Emissions.zip2008 No2461022000 Emulsified AsphaltAsphalt_Paving_Emulsified_2461022000_Documentation.zipAsphalt_Paving_Emulsified_2461022000_Emissions.zip2008 NoAviation GasolineDistribution: Stage I2501080050Aviation Gasoline:Stage IAviation_Gasoline_Distribution_Stage_I_2501080050_Documentation.zipAviation_Gasoline_Distribution_Stage_I_2501080050_Emissions.zip2008 NoAviation GasolineDistribution: Stage II2501080100Aviation Gasoline:Stage IIAviation_Gasoline_Distribution_Stage_II_2501080100_Documentation.zipAviation_Gasoline_Distribution_Stage_II_2501080100_Emissions.zip2008 NoCommercial Cooking2302002nnn2302003nnnCommercial CookingCommercial_Cooking_2302002nnn_Documentation.zipCommercial_Cooking_2302002nnn_Emissions.zip2008 NoConstruction Dust2311010000 Residential ConstructionResidential_Construction_2311010000_Documentation.zipResidential_Construction_2311010000_Emissions.zip2008 Yes2311020000 Non-Residential ConstructionNon-Residential_Construction_2311020000_Documentation.zipNon-Residential_Construction_2311020000_Emissions.zip2008 Yes2311030000 Road ConstructionRoad_Construction_2311030000_Documentation.zipRoad_Construction_2311030000_Emissions.zip2006 NoFertilizer Application 28017000nn Fertilizer ApplicationFertilizer_Application_28017000nn_Documentation.zipFertilizer_Application_28017000nn_Emissions.zip2007 NoGasoline Distribution(SEMAP emissions weredeveloped for Stage IGasoline Service StationUnloading using NEImethods with S/L agencyapproved inputs)25010110nn25010120nnPortable Fuel ContainersPortable_Fuel_Containers_25010110nn_25010120nn_Documentation.zipPortable_Fuel_Containers_25010110nn_25010120nn_Emissions.zip2008 No2501050120Gasoline Distribution Stage I;Bulk TerminalsGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_Bulk_Terminals_2501050120_Emissions.zip2008 Yes2501055120Gasoline Distribution Stage I;Bulk PlantsGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_Bulk_Plants_2501055120_Emissions.zip2008 Yes250106005nGasoline Distribution Stage I;Gasoline Service StationUnloadingGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_Service_Station_Unloading_250106005n_Emissions.zip2008YesJanuary 2012Final Report7Source CategorySource ClassificationCode(s)Source Classification CodeDescriptionLink to Emission CalculationDocumentationLink to Emission CalculationWorkbookYear ofActivityDataPoint SourceComponent2501060100Gasoline Distribution Stage II;Gasoline Service StationsGasoline_Distribution_Stage_II_Documentation.zipGasoline_Distribution_Stage_II_Gasoline_Service_Stations_2501060100_Emissions.zip2008 Yes2501060201Gasoline Distribution Stage I;Underground storage tank,breathing and emptyingGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_UST_Breathing_and_Emptying_2501060201_CAP_Emissions.zip2008 Yes2505030120Gasoline Distribution Stage I;Tank Trucks in TransitGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_Tank_Trucks_in_Transit_2505030120_Emissions.zip2008 Yes2505040120Gasoline Distribution Stage I;PipelinesGasoline_Distribution_Stage_I_Documentation.zipGasoline_Distribution_Stage_I_Pipelines_2505040120_CAP_Emissions.zip2008 NoOpen Burning(NEI emissions for OpenBurning of Land ClearingDebris were transmitted toAMEC for incorporation intoSEMAP’s fire inventory)2610000100Open Burning - Yard Waste -LeavesOpen_Burning_Yard_Waste_Leaf_2610000100_and_Brush_2610000400_Documentation.zipOpen_Burning_Yard_Waste_Leaf_261000100_Emissions.zip2008 No2610000400Open Burning - Yard Waste -BrushOpen_Burning_Yard_Waste_Leaf_2610000100_and_Brush_2610000400_Documentation.zipOpen_Burning_Yard_Waste_Brush_261000400_Emissions.zip2008 No2610000500Open Burning-Land ClearingDebrisOpen_Burning_Land_Clearing_Debris_2610000500_Documentation.zipOpen_Burning_Land_Clearing_Debris_2610000500_Emissions.zipMultipleYearsNo2610030000Open Burning-HouseholdWasteOpen_Burning_MSW_2610030000_Documentation.zipOpen_Burning_MSW_2610030000_Emissions.zip2008 NoPaved and Unpaved Roads2294000000Paved Road DustPaved_Roads_2294000000_Documentation.zipPaved_Roads_2294000000_Emissions.zip2007 No2296000000 Unpaved Road DustUnpaved_Roads_2296000000_Documentation.zipUnpaved_Roads_2296000000_Emissions.zip2007 NoPublicly Owned TreatmentWorks (POTW)2630020000Publicly Owned TreatmentWorks (POTW)Publicly_Owned_Treatment_Works_2630020000_Documentation.zipPublicly_Owned_Treatment_Works_630020000_Emissions.zip2008 YesResidential Heating(SEMAP Residential WoodCombustion/Wax Firelogemissions were calculatedusing NEI’s RWC Tool withSESARM-revised inputs)2104001000 Residential Anthracite CoalResidential_Coal_2104001000_2104002000_Documentation.zipResidential_Coal_2104001000_2104002000_Emissions.zip2006 No2104002000 Residential Bituminous CoalResidential_Coal_2104001000_2104002000_Documentation.zipResidential_Coal_2104001000_2104002000_Emissions.zip2006 No2104004000 Residential Distillate OilResidential_Distillate_Fuel_2104004000_Documentation.zipResidential_Distillate_Fuel_2104004000_Emissions.zip2006 NoJanuary 2012Final Report8Source CategorySource ClassificationCode(s)Source Classification CodeDescriptionLink to Emission CalculationDocumentationLink to Emission CalculationWorkbookYear ofActivityDataPoint SourceComponent2104006000 Residential Natural GasResidential_Natural_Gas_2104006000_Documentation.zipResidential_Natural_Gas_2104006000_Emissions.zip2006 No2104007000Residential LPGResidential_LPG_2104007000_Documentation.zipResidential_LPG_2104007000_Emissions.zip2006 No2104008nnn2104009000Residential WoodCombustion and WaxFirelogsResidential_Wood_Combustion_Documentation.zipRWC_2008_Toolv4.1_Feb09_2010.zipInputsrepresent variousyearsNo2104011000 Residential KeroseneResidential_Kerosene_2104011000_Documentation.zipResidential_Kerosene_2104011000_Emissions.zip2006 NoSolvent Usage - SurfaceCoatings2401001000 Architectural CoatingsSolvent_Utilization_Documentation.zipSurface_Coating_Architectural_Coating_2401001000_Emissions.zip2008 No2401005000 Automobile RefinishingSolvent_Utilization_Documentation.zipSurface_Coating_Automobile_Refinishing_2401005000_Emissions.zip2006 Yes2401008000Traffic PaintsSolvent_Utilization_Documentation.zipSurface_Coating_Traffic_Painting_2401008000_Emissions.zip2007 No2401015000 Factory Finished WoodSolvent_Utilization_Documentation.zipSurface_Coating_Factory_Finished_Wood_2401015000_Emissions.zip2006 Yes2401020000 Wood Furniture and FixturesSolvent_Utilization_Documentation.zipSurface_Coating_Wood_Furniture_and_Fixtures_401020000_Emissions.zip2006 Yes2401025000Metal FurnitureSolvent_Utilization_Documentation.zipSurface_Coating_Metal_Furniture_2401025000_Emissions.zip2006 Yes2401030000 Paper, Film and FoilSolvent_Utilization_Documentation.zipSurface_Coating_Paper_Film_and_Foil_2401030000_Emissions.zip2006 Yes2401040000Metal CansSolvent_Utilization_Documentation.zipSurface_Coating_Metal_Can_Coating_2401040000_Emissions.zip2006 Yes2401045000 Metal Sheet, Strip and CoilsSolvent_Utilization_Documentation.zipSurface_Coating_Metal_Sheet_Strip_Coil_2401045000_Emissions.zip2006 Yes2401055000 Machinery and EquipmentSolvent_Utilization_Documentation.zipSurface_Coating_Machinery_and_Equipment_2401055000_Emissions.zip2006 Yes2401060000AppliancesSolvent_Utilization_Documentation.zipSurface_Coating_Appliances_2401060000_Emissions.zip2006 YesJanuary 2012Final Report9Source CategorySource ClassificationCode(s)Source Classification CodeDescriptionLink to Emission CalculationDocumentationLink to Emission CalculationWorkbookYear ofActivityDataPoint SourceComponent2401065000Electronic and OtherElectrical CoatingsSolvent_Utilization_Documentation.zipSurface_Coating_Electronic_and_Other_Electrical_Coatings_2401065000_Emissions.zip2006 Yes2401070000Motor VehiclesSolvent_Utilization_Documentation.zipSurface_Coating_Motor_Vehicles_2401070000_Emissions.zip2006 Yes2401075000AircraftSolvent_Utilization_Documentation.zipSurface_Coating_Aircraft_2401075000_Emissions.zip2006 Yes2401080000Marine coatingsSolvent_Utilization_Documentation.zipSurface_Coating_Marine_Coatings_2401080000_Emissions.zip2006 Yes2401085000RailroadsSolvent_Utilization_Documentation.zipSurface_Coating_Railroad_2401085000_Emissions.zip2006 No2401090000 Misc. ManufacturingSolvent_Utilization_Documentation.zipSurface_Coating_Misc_Manufacturing_2401090000_Emissions.zip2006 Yes2401100000Industrial MaintenanceCoatingsSolvent_Utilization_Documentation.zipSurface_Coating_Industrial_Maintenance_Coating_2401100000_Emissions.zip2008 No2401200000Other Special PurposeCoatingsSolvent_Utilization_Documentation.zipSurface_Coating_Other_Special_Purpose_Coating_2401200000_Emissions.zip2008 NoSolvent Usage - Other2415000000Cleaning Products: Industrialand InstitutionalSolvent_Utilization_Documentation.zipCleaning_Products_Industrial_and_Institutional_2415000000_Emissions.zip2006 Yes2420000000Dry CleaningSolvent_Utilization_Documentation.zipDry_Cleaning_2420000000_Emissions.zip2006 No2425000000Graphic ArtsSolvent_Utilization_Documentation.zipGraphic_Arts_2425000000_Emissions.zip2006 Yes2460100000Consumer & Commercial -Personal Care Products(Cosmetics and Toiletries)Solvent_Utilization_Documentation.zipConsumer_Solvents-Personal_Care_Products_(Cosmetics_and_Toiletries)_2460100000_Emissions.zip2008 No2460200000Consumer & Commercial -Household Cleaning ProductsSolvent_Utilization_Documentation.zipConsumer_Solvents-Household_Cleaning_Products_2460200000_Emissions.zip2008 No2460400000Consumer &Commercial-Automotive AftermarketSolvent_Utilization_Documentation.zipConsumer_SolventsAutomotive_Aftermarket_2460400000_Emissions.zip2008 NoJanuary 2012Final Report10Source CategorySource ClassificationCode(s)Source Classification CodeDescriptionLink to Emission CalculationDocumentationLink to Emission CalculationWorkbookYear ofActivityDataPoint SourceComponent2460500000Consumer & Commercial-Coatings and RelatedProductsSolvent_Utilization_Documentation.zipConsumer_SolventsCoatings_and_Related_Products_2460500000_Emissions.zip2008 No2460600000Consumer & Commercial -Adhesives and SealantsSolvent_Utilization_Documentation.zipConsumer_Solvents-Adhesives_and_Sealants_2460600000_Emissions.zip2008 No2460800000Consumer & Commercial-FIFRA Regulated ProductsSolvent_Utilization_Documentation.zipConsumer_Solvents_FIFRA_Regulated_Products_2460800000_Emissions2008 No2460900000Consumer & Commercial -Misc. ProductsSolvent_Utilization_Documentation.zipConsumer_Solvents-Misc_Products_2460900000_Emissions.zip2008 No

# January 2012



# 11 Final Report 

# a. Adjustment of NEI Data to Reflect 2007 Activity Level s 7



# When the 2008 nonpoint source NEI reflected 2007 ac tivity data, TranSystems incorporated the 2008 NEI e mission

estimates as the default SEMAP area source inventor y. When a source category’s NEI data reflected 200 6 or 2008

emissions activity data, TranSystems updated the NEI estimates to reflect 2007 emission activity levels . Table II-3

documents these specific adjustments.

For many area source categories, emissions activity data are not available at the county-level. In the se cases,

county-level emissions are estimated using two sets of activity data: one set reflecting state or reg ional-level

emissions activity (e.g., volume of natural gas con sumed by the residential sector in each state), and the other set

representing data that are used to allocate emissio ns activity to the county-level (e.g., number of ho uses using

natural gas as the primary heating fuel in each cou nty). Specifically, the “Backcasting or Forecastin g Methodology”

column in Table II-3 presents the approach used to update emissions activity data to represent 2007, a nd the

“County Allocation Method” column identifies the ap proach used to update the county allocation data. As noted in

Table II-3, all county allocation data were not upda ted to 2007. These data were not updated because ofthe level-ofeffort that would be involved, and the fact that th ese data are generally not expected to differ signi ficantly from yearto-year.

b. Adjustment of NEI Data to Remove Activity Reflected in t he Point Source Inventory

To prevent double-counting of emissions in the stati onary point source and area source emissions invent ories, it was

necessary to perform point source subtractions on s ome of the source categories in the TranSystems defa ult area

source inventory. To facilitate the point source su btractions, TranSystems prepared crosswalks that lin k area SCCs

to point SCCs. These crosswalks are presented in Ap pendix A. The general point source subtraction appr oach

consisted of the following steps:

1. Compile 2007 point source emissions and control eff iciency data provided by each state for the applica ble

point SCCs.

2. Identify potential quality assurance issues for S/L agency review;

3. Revise control efficiency data to incorporate S/L a gency comments;

4. Back-calculate 2007 uncontrolled point source emiss ions from reported emissions and control efficiency

data -- e.g., 40 tpy of controlled NO

x 

# emissions and 80 percent control efficiency = 50 t py of uncontrolled

NO

x 

# emissions.

5. Sum the emissions for each record from step 4 to th e state-level to yield state total uncontrolled poi nt

source emissions by pollutant.

6. For each pollutant and state, compute the fraction o f total 2007 state-level emissions in the 2007

TranSystems default inventory represented by area so urces (using step 5 total point source uncontrolled

emissions).

7. Multiply the emission estimates in the draft base y ear inventory by the appropriate percentages in ste p 6 to

yield area source emissions.

TranSystems performed the point source subtractions at the state- rather than county-level because of t he

uncertainty associated with the NEI county emission allocations in that actual county-level emissions activity data are

generally not available (i.e., a surrogate indicato r such as employment is typically used to allocate state-level activity

to counties). 8 

# Although the final inventory reflected Georgia’s request to perform Georgia’s point source subtracti ons

at the county-level, Georgia’s revised final invent ory reflects subtractions at the state-level.

7 

# In addition, TranSystems incorporated silt content inputs provided by Alabama for updated NEI-based em issions estimation

calculations used for the residential and nonreside ntial construction dust categories (SCCs 2311010000 and 2311020000).

8 

# Efforts to perform subtractions at the county-level commonly result in negative emission estimates.January 2012Final Report12Table II-3. Methods for Updating 2008 NEI Estimates that Are Not Based on 2007 Emissions ActivitySource CategorySourceClassificationCode(s)Source Classification CodeDescriptionYear ofActivityDataBackcasting or ForecastingMethodologyIs UpdateActualActivityData?GeographicResolution ofBackcast/ ForecastDataCounty Allocation MethodPoint SourceComponentAsphalt Paving2461021000 Cutback Asphalt 2008Recalculatedusing 2007 asphaltusageYes State Allocated using 2007 county VMT No2461022000 Emulsified Asphalt 2008Recalculated using 2007 asphaltusageYes State Allocated using 2007 county VMT NoAviation GasolineDistribution: Stage I2501080050 Aviation Gasoline: Stage I 2008Recalculated using 2007 AvGasconsumptionYes NationalAllocated to district-level according toAvGas consumption reported for eachPetroleum Administration District andthen to county-level using 2008 LTOdata for general aviation flightsNoAviation GasolineDistribution: Stage II2501080100 Aviation Gasoline: Stage II 2008Recalculated using 2007 AvGasconsumptionYes NationalAllocated to district-level according toAvGas consumption reported for eachPetroleum Administration District andthen to county-level using 2008 LTOdata for general aviation flightsNoCommercial Cooking2302002nnn2302003nnnCommercial Cooking 2008Recalculated using 2007population estimatesYes CountyNoConstruction Dust2311010000 Residential Construction 2008Recalculated surface soil estimateusing new privately ownedhousing units started in 2007 (allother activity data reflects 2007)Yes RegionalAllocated to county using 2007 annualhousing unitsYes2311020000 Non-Residential Construction 2008Recalculated using 2007 value ofconstruction put in placeYes NationalDid not revise the county allocation(based on 2006 non-residentialconstruction employment)Yes2311030000 Road Construction 2006Recalculated using 2007 FHWAcapital outlaysYes StateNEI county allocation data (number ofbuilding starts) are 2007NoGasoline Distribution25010110nn25010120nnPortable Fuel Containers 2008Estimated 2007 using a linear fitbetween 2002 and 2010 emissionsN/A CountyThis is the same procedure used toestimate 2008 estimates for NEINo2501050120Gasoline Distribution Stage I;Bulk Terminals2008Recalculated using 2007 nationalvolume of wholesale gasolinesuppliedYes NationalAllocated to state-level using 2007refinery, bulk terminal, and natural gasplant stocks of motor gasoline and thento county-level using 2007 CountyBusiness Patterns for NAICS code42471Yes2501055120Gasoline Distribution Stage I;Bulk Plants2008Recalculated using EIA's estimateof 2007 finished motor gasolinesuppliedNo NationalAllocated to county-level using 2007County Business Patterns for NAICScode 42471Yes2501060100Gasoline Distribution Stage II;2008Applied county-levelVMTratio:YesCountyYesJanuary 2012Final Report13Source CategorySourceClassificationCode(s)Source Classification CodeDescriptionYear ofActivityDataBackcasting or ForecastingMethodologyIs UpdateActualActivityData?GeographicResolution ofBackcast/ ForecastDataCounty Allocation MethodPoint SourceComponentGasoline Service StationsVMTfrom 2007 NMIM run :VMTfrom 2008 NMIM run*2501060201Gasoline Distribution Stage I;Underground storage tank,breathing and emptying2008Applied county-level CO2emissions ratio: CO2 emissionsfrom 2007 NMIM run : CO2emissions from 2008 NMIM runNo CountyYes2505030120Gasoline Distribution Stage I;Tank Trucks in Transit2008Applied county-levelCO2emissions ratio: CO2 emissionsfrom 2007 NMIM run : CO2emissions from 2008 NMIM runNo CountyYes2505040120Gasoline Distribution Stage 1;Pipelines2008Recalculated using 2007 nationalvolume of wholesale gasolinesuppliedYes NationalAllocated to PAD-level using 2007finished motor gasoline moved bypipeline in each PAD in 2007 and thento county-level using 2007 CountyBusiness Patterns for NAICS code42471NoOpen Burning2610000100Open Burning - Yard Waste -Leaves2008Recalculated using 2007population estimateYes CountyNo2610000400Open Burning - Yard Waste -Brush2008Recalculated using 2007population estimateYes CountyNo2610030000Open Burning - HouseholdWaste2008Recalculated using 2007population estimateYes CountyNoPublicly OwnedTreatment Works(POTW)2630020000Publicly Owned TreatmentWorks (POTW)2008Estimated 2007 using a linear fitbetween 2004 and 2010 POTWflow rates. Allocate to county-levelusing 2007 population.Yes NationalThis is the same procedure used toestimate 2008 estimates for NEI.Allocated to county-level using 2007population estimate.YesResidential Heating2104001000 Residential Anthracite Coal 2006Recalculatedusing 2007 coalconsumption data and 2007 ratioof anthracite to bituminous coalconsumptionYes StateCounty allocation based on 2000Census dataNo2104002000 Residential Bituminous Coal 2006Recalculated using 2007 coalconsumption data and 2007 ratioof anthracite to bituminous coalconsumptionYes StateCounty allocation based on 2000Census dataNo2104004000 Residential Distillate Oil 2006Recalculated using 2007 distillateoil consumptionYes StateCounty allocation based on 2000Census dataNo2104006000 Residential Natural Gas 2006Recalculated using 2007 naturalgas consumptionYes StateCounty allocation based on 2000Census dataNoJanuary 2012Final Report14Source CategorySourceClassificationCode(s)Source Classification CodeDescriptionYear ofActivityDataBackcasting or ForecastingMethodologyIs UpdateActualActivityData?GeographicResolution ofBackcast/ ForecastDataCounty Allocation MethodPoint SourceComponent2104007000 Residential LPG 2006Recalculated using 2007 LPGconsumptionYes StateCounty allocationbased on 2000Census dataNo2104011000 Residential Kerosene 2006Recalculated using 2007 keroseneconsumptionYes StateCounty allocation based on 2000Census dataNoSolvent Usage -Surface Coatings2401001000 Architectural Coatings 2008Recalculatedusing 2007population estimateYes CountyNo2401005000 Automobile Refinishing 2006Recalculated using 2007employment dataYes CountyYes2401015000 Factory Finished Wood 2006Recalculated using 2007employment dataYes CountyYes2401020000 Wood Furniture and Fixtures 2006Recalculated using 2007employment dataYes CountyYes2401025000 Metal Furniture 2006Recalculated using 2007employment dataYes CountyYes2401030000 Paper, Film and Foil 2006Recalculated using 2007employment dataYes CountyYes2401040000 Metal Cans 2006Recalculated using 2007employment dataYes CountyYes2401045000 Metal Sheet, Strip and Coils 2006Recalculated using 2007employment dataYes CountyYes2401055000 Machinery and Equipment 2006Recalculated using 2007employment dataYes CountyYes2401060000 Appliances 2006Recalculated using 2007employment dataYes CountyYes2401065000Electronic and Other ElectricalCoatings2006Recalculated using 2007employment dataYes CountyYes2401070000 Motor Vehicles 2006Recalculated using 2007employment dataYes CountyYes2401075000Aircraft2006Recalculated using 2007employment dataYes CountyYes2401080000 Marine coatings 2006Recalculated using 2007employment dataYes CountyYes2401085000Railroads2006Recalculated using 2007employment dataYes CountyNo2401090000 Misc. Manufacturing 2006Recalculated using 2007employment dataYes CountyYes2401100000Industrial MaintenanceCoatings2008Recalculatedusing 2007population estimateYes CountyNoJanuary 2012Final Report15Source CategorySourceClassificationCode(s)Source Classification CodeDescriptionYear ofActivityDataBackcasting or ForecastingMethodologyIs UpdateActualActivityData?GeographicResolution ofBackcast/ ForecastDataCounty Allocation MethodPoint SourceComponent2401200000Other Special PurposeCoatings2008Recalculated using 2007population estimateYes CountyNoSolvent Usage - Other2415000000Cleaning Products: Industrialand Institutional2006Recalculatedusing 2007employment dataYes CountyYes2420000000 Dry Cleaning 2006Recalculated using 2007employment dataYes CountyNo2425000000 Graphic Arts2006Recalculated using 2007employment dataYes CountyYes2460100000Consumer & Commercial-Personal Care Products(Cosmetics and Toiletries)2008Recalculated using 2007population estimateYes CountyNo2460200000Consumer & Commercial-Household Cleaning Products2008Recalculated using 2007population estimateYes CountyNo2460400000Consumer & Commercial-Automotive Aftermarket2008Recalculated using 2007population estimateYes CountyNo2460500000Consumer & Commercial-Coatings and Related Products2008Recalculated using 2007population estimateYes CountyNo2460600000Consumer & Commercial-Adhesives and Sealants2008Recalculated using 2007population estimateYes CountyNo2460800000Consumer & Commercial-FIFRA Regulated Products2008Recalculated using 2007population estimateYes CountyNo2460900000Consumer & Commercial-Misc. Products2008Recalculated using 2007population estimateYes CountyNo*Note that Stage II gasoline refueling VOC emissions were revised from the emissions reported in the final version of the 2007 SEMAP inventory, using updated 2007/2008 VMT adjustment factor ratios. Theupdated ratios reflect incorporation ofthe 2007 VMT data that was used as input to MOVES onroad mobile source emissions modeling runs.

# January 2012

Final Report 

# 16 

# As a final step, TranSystems set post-subtraction P M2.5-PRI emissions equal to PM10-PRI emissions in c ases

where the initial post-subtraction emissions indica ted that PM2.5-PRI emissions were greater than PM10 -PRI

emissions.

Because of the inconsistent reporting of throughput data in the SEMAP point source inventory, throughp ut data were

used in the point source subtraction procedure in o nly a limited number of cases. These cases are list ed below in

Table II-4. For these areas/SCCs, all pollutants’ to tal emissions are adjusted by the same percentage. For a few

area source categories, it was necessary to incorpo rate source category-specific point source subtract ion

procedures. Appendix A summarizes the specific poi nt source subtraction approaches for these source c ategories.

Table II-4. Throughput-Based Area Source Emission Adjustments

Area SCC Area Source %

Jefferson County, KY 2102008000 95.66

South Carolina 2102002000 25.35

2102004000 0.00

2102005000 0.00

2102006000 21.33

2102007000 0.00

2102008000 43.40

2103004000 93.14

2103006000 94.10

2103007000 99.84

Knox County, TN 2102006000 76.71

2103006000 99.13

Tennessee - Rest of

State 2103008000 49.36

2401015000 94.40



# 2. Estimation of Area Source Emissions from Industrial and Comm ercial/Institutional Fuel Combustion

In early 2010, the 2008 NEI data for the ICI fuel c ombustion categories represented total emission activity estimates,

rather than area source emission estimates. Because emission estimates were not av ailable and because of the

relative importance of this category, TranSystems re commended that 2007 ICI combustion area source emis sion

estimates be developed as part of this project. Th is section documents the emission inventory develop ment

methodology that TranSystems used in preparing 2007 year ICI fuel combustion area source emission estim ates for

the SESARM states. The following are elements of th e methodology that provide improvements over the 20 08 NEI

methodology:

• 

# Obtained Industrial and Commercial/Institutional en ergy consumption by fuel type and SESARM state for

the year 2007 from the Energy Information Administr ation (EIA)’s State Energy Data System (SEDS) – the

2008 NEI used 2006 year data;

# January 2012

Final Report 

# 17 • 

# Obtained geographic- and year-specific estimates of non-fuel use consumption of industrial energy from the

2006 Manufacturing Energy Consumption Survey (MECS) – the 2008 NEI used data from the 2002 MECS

survey;

• 

# Applied a county allocation procedure that reflects the energy-intensity of each industrial sector – t he 2008

NEI methods only reflect the number of employees in each sector; and

• 

# Updated SO 2 

# emission factors to reflect coal sulfur content es timates for coal used in the industrial sector in

2007 – a recent review of industrial coal sulfur co ntent values concluded that the NEI values are base d on

unrepresentative data (Pechan, 2009b).

Table II-5 identifies the SCCs for which TranSystems prepared ICI fuel combustion area source emission e stimates.

The key data inputs in the emissions estimation meth odology are:

1. Total Industrial and total Commercial/Institutional energy consumption by fuel type and SESARM state fo r

the year 2007;

2. Estimates of the percentage of total ICI distillate fuel and liquefied petroleum gas (LPG) consumption from

stationary sources;

3. Industrial energy consumption used for non-fuel pur poses by fuel type and state in 2006;

4. ICI energy consumption by fuel type for point sourc es by SESARM state in year 2007;

5. Emission factors relating emission rates to volume of energy consumed by fuel type for the ICI sectors ;

6. Sulfur content of coal consumed in the ICI sectors by state in year 2007;

7. County-level Industrial sector energy consumption e stimates by state for year 2007; and

8. County-level Commercial/Institutional sector employ ment by state for the year 2006. 9



# Table II.5. ICI Fuel Combustion Area Source Classification Codes

SCC DESCRIPTION

2102001000 Stationary Source Fuel Combustion; Industrial; Anth racite Coal; Total: All Boiler Types

2102002000 Stationary Source Fuel Combustion; Industrial; Bitu minous/Subbituminous Coal; Total: All Boiler Types

2102004000 Stationary Source Fuel Combustion; Industrial; Dist illate Oil; Total: Boilers and IC Engines

2102005000 Stationary Source Fuel Combustion; Industrial; Residual Oil; Total: All Boiler Types

2102006000 Stationary Source Fuel Combustion; Industrial; Natu ral Gas; Total: Boilers and IC Engines

2102007000 Stationary Source Fuel Combustion; Industrial; Liqu id Petroleum Gas; Total: All Boiler Types

2102008000 Stationary Source Fuel Combustion; Industrial; Wood ; Total: All Boiler Types

2102011000 Stationary Source Fuel Combustion; Industrial; Kero sene; Total: All Boiler Types

2103001000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Anthracite Coal; Total: All Boiler Types

2103002000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Bituminous/Subbituminous Coal; Total: All Boiler Types

2103004000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Distillate Oil ; Total: Boilers and IC Engines

2103005000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Residual Oil; Total: All Boiler Types

2103006000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Natural Gas; Total: Boilers and IC Engines

2103007000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Liquid Petroleum Gas; Total: All Combusto r Types

2103008000 Stationary Source Fuel Combustion; Commercial/Insti tutional; Wood; Total: All Boiler Types

2103011000 Stationary Source Fuel Combustion; Commercial/Institutional; K erosene; Total: All Combustor Types

9 

# To conserve project resources, Pechan relied on 20 06 employment data compiled in support of the 2008 NEI rather than

develop 2007 employment data (note that year-to-yea r county employment proportions are expected to rem ain relatively

constant).

# January 2012

Final Report 

# 18 

# The following sections describe the methodology/data source(s) for developing each of these data inputs , and the

source(s) of information for each of these data ele ments. In selecting the information sources for ea ch of these data

elements, TranSystems evaluated the completeness, re presentativeness, comparability, and accuracy crite ria

identified in the Quality Assurance Project Plan (Q APP) for this project. For example, information sou rces that

provide data specific to the source category/geogra phy/inventory period were selected over those that were less

specific.

a. Total ICI Energy Consumption

For total Industrial and total Commercial/Institutio nal energy consumption by fuel type/state, TranSyste ms primarily

used the same source that EPA uses in developing IC I combustion emission estimates for the NEI –EIA’s SEDS

(EIA, 2009a). The SEDS provides total energy consum ption estimates by sector, state, fuel type, and ye ar. To

facilitate use with the criteria pollutant emission factors, TranSystems compiled the SEDS energy consu mption data

in both sets of units provided by the EIA: physica l units and British thermal units (Btus). For esti mates of industrial

distillate consumption, TranSystems relied on estima tes reported in EIA’s “Fuel Oil and Kerosene Sales” (EIA,

2009b). This source is preferred over the SEDS data because it provides additional sectoral detail tha t is needed to

perform the stationary source energy consumption ad justments described below.

b. Stationary Source Energy Consumption

To avoid double-counting with energy consumption acc ounted for in mobile source inventories, it was nec essary to

adjust 2007 year SEDS distillate and LPG consumptio n estimates for mobile source fuel consumption. For LPG, the

adjustments account for energy consumption reflecte d in the nonroad mobile sector. The adjustments we re

performed by subtracting estimated proportions of t otal Industrial sector and Commercial sector consum ption

computed from a national NONROAD model run. TranSys tems compiled national LPG consumption estimates fo r

relevant SCCs from a 2006 run of EPA’s NONROAD mode l (a 2006 run was performed in support of the NEI—i t is

not anticipated that the percentages differ conside rably between 2006 and 2007). Table II-6 identifie s a complete list

of nonroad SCCs associated with Industrial and Comm ercial sector LPG. The shaded entries in this table indicate

where NONROAD reports LPG consumption. This procedu re estimates that nonroad mobile sources account fo r 9

percent of Industrial sector, and 18 percent of Com mercial sector LPG consumption. The SEDS LPG consum ption

estimates for each state/sector were adjusted downw ard using these percentages.

For distillate oil, it was necessary to remove energ y consumption reflected in onroad/nonroad mobile so urce emission

inventories. To facilitate this step, TranSystems us ed more detailed distillate fuel consumption estima tes reported in

EIA’s “Fuel Oil and Kerosene Sales,” and stationary source fuel consumption percentage assumptions used in the

regulatory impact analysis for EPA’s nonroad diesel emissions rulemaking (EPA, 2003a). Table II-7 disp lays the

assumptions that were applied to the state-level In dustrial sector distillate fuel consumption estimat es reported in

“Fuel Oil and Kerosene Sales” to estimate Industrial sector stationary source consumption. Table II-8 i dentifies the

assumptions that were applied to estimate total sta tionary source Commercial/Institutional sector cons umption.January 201219Final ReportTable II-6. LPG Nonroad Mobile Source Classification CodesSCCDescription_2Description_3Description_4Industrial Sector2267002000 LPGConstruction and Mining EquipmentAll2267002003LPGConstruction and Mining EquipmentPavers2267002006LPGConstruction and Mining EquipmentTampers/Rammers2267002009LPGConstruction and Mining EquipmentPlate Compactors2267002015LPGConstruction and Mining EquipmentRollers2267002018LPGConstruction and Mining EquipmentScrapers2267002021LPGConstruction and Mining EquipmentPaving Equipment2267002024LPGConstruction and Mining EquipmentSurfacing Equipment2267002027LPGConstruction and Mining EquipmentSignal Boards/Light Plants2267002030LPGConstruction and Mining EquipmentTrenchers2267002033LPGConstruction and Mining EquipmentBore/Drill Rigs2267002036LPGConstruction and Mining EquipmentExcavators2267002039LPGConstruction and Mining EquipmentConcrete/Industrial Saws2267002042LPGConstruction and Mining EquipmentCement and MortarMixers2267002045LPGConstruction and Mining EquipmentCranes2267002048LPGConstruction and Mining EquipmentGraders2267002051LPGConstruction and Mining EquipmentOff-highway Trucks2267002054LPGConstruction and Mining EquipmentCrushing/Processing Equipment2267002057LPGConstruction and Mining EquipmentRough Terrain Forklifts2267002060LPGConstruction and Mining EquipmentRubber Tire Loaders2267002063 LPGConstruction and Mining EquipmentRubber Tire Tractors/Dozers2267002066LPGConstruction and Mining EquipmentTractors/Loaders/Backhoes2267002069 LPGConstruction and Mining EquipmentCrawler Tractor/Dozers2267002072LPGConstruction and Mining EquipmentSkid Steer Loaders2267002075LPGConstruction and Mining EquipmentOff-Highway Tractors2267002078LPGConstruction and Mining EquipmentDumpers/Tenders2267002081LPGConstruction and Mining EquipmentOther Construction Equipment2267003000LPGIndustrial EquipmentAll2267003010LPGIndustrial EquipmentAerial Lifts2267003020LPGIndustrial EquipmentForklifts2267003030LPGIndustrial EquipmentSweepers/Scrubbers2267003040LPGIndustrial EquipmentOther General Industrial EquipmentJanuary 201220Final ReportSCCDescription_2Description_3Description_42267003050LPGIndustrial EquipmentOther Material Handling Equipment2267003060LPGIndustrial EquipmentAC\Refrigeration2267003070LPGIndustrial EquipmentTerminal Tractors2267005000LPGAgricultural EquipmentAll2267005010LPGAgricultural Equipment2-Wheel Tractors2267005015LPGAgricultural EquipmentAgricultural Tractors2267005020LPGAgricultural EquipmentCombines2267005025LPGAgricultural EquipmentBalers2267005030LPGAgricultural EquipmentAgricultural Mowers2267005035LPGAgricultural EquipmentSprayers2267005040LPGAgricultural EquipmentTillers >6 HP2267005045LPGAgricultural EquipmentSwathers2267005050LPGAgricultural EquipmentHydro-power Units2267005055LPGAgricultural EquipmentOther Agricultural Equipment2267005060LPGAgricultural EquipmentIrrigation Sets2267007000 LPGLogging EquipmentAll2267007005 LPGLogging EquipmentChain Saws > 6 HP2267007010 LPGLogging EquipmentShredders > 6 HP2267007015 LPGLogging EquipmentForest Eqp – Feller/Bunch/Skidder2267009000 LPGUnderground Mining EquipmentAll2267009010 LPGUnderground Mining EquipmentOther Underground Mining Equipment2267010000 LPGIndustrial EquipmentAll2267010010 LPGIndustrial EquipmentOther Oil Field EquipmentCommercial Sector2267004011 LPGLawn and Garden EquipmentLawn Mowers (Commercial)2267004016LPGLawn and Garden EquipmentRotary Tillers < 6 HP (Commercial)2267004021LPGLawn and Garden EquipmentChain Saws < 6 HP (Commercial)2267004026LPGLawn and Garden EquipmentTrimmers/Edgers/Brush Cutters (Commercial)2267004031LPGLawn and Garden EquipmentLeafblowers/Vacuums (Commercial)2267004036LPGLawn and Garden EquipmentSnowblowers (Commercial)2267004041LPGLawn and Garden EquipmentRear Engine Riding Mowers (Commercial)2267004046LPGLawn and Garden EquipmentFront Mowers (Commercial)2267004051LPGLawn and Garden EquipmentShredders < 6 HP (Commercial)2267004056LPGLawn and Garden EquipmentLawn and Garden Tractors (Commercial)2267004061LPGLawn and Garden EquipmentWood Splitters (Commercial)2267004066LPGLawn and Garden EquipmentChippers/Stump Grinders (Commercial)January 201221Final ReportSCCDescription_2Description_3Description_42267004071LPGLawn and Garden EquipmentTurf Equipment (Commercial)2267004076LPGLawn and Garden EquipmentOther Lawn and Garden Equipment (Commercial)2267006000 LPGCommercial Equipment All2267006005LPGCommercial EquipmentGenerator Sets2267006010LPGCommercial EquipmentPumps2267006015LPGCommercial EquipmentAir Compressors2267006020LPGCommercial EquipmentGas Compressors2267006025LPGCommercial EquipmentWelders2267006030LPGCommercial EquipmentPressure Washers2267006035LPGCommercial EquipmentHydro-power Units2267008000LPGAirport Ground Support EquipmentAll2267008005LPGAirport Ground Support EquipmentAirport Ground Support EquipmentNote: EPA’s NONROAD model reports emissions/fuel consumption for the shaded entries.

# January 2012



# 22 Final Report 

# Table II-7. Assumptions Used to Estimate Industrial Sector St ationary Source Distillate Fuel Consumption

Sector Distillate Fuel Type % of Total



# Consumption from

Stationary Sources

Industrial No. 1 Distillate Fuel Oil 60

No. 2 Distillate Fuel Oil 100

No. 2 Distillate/Low and High Sulfur Diesel 15 a



# No. 4 Distillate Fuel Oil 100

Farm Diesel 0

Other Distillate Fuel Oil 100

Off

- Highway



# (Construction and Other) Distillate Fuel Oil 5

Oil Company Distillate Fuel Oil 50

a 

# This value differs from the 0 percent assumption a dopted in EPA’s nonroad diesel emissions rulemaking because it is

known that some diesel fuel is used by stationary s ources (a 15 percent value was selected for use as an approximate

mid-point of a potential range of 8 to 24 percent s tationary source use computed from a review of nati onal data from the

EIA’s Manufacturing Energy Consumption Survey and “Fuel Oil and Kerosene Sales”).



# Table II-8. Assumptions Used to Estimate Commercial/Instituti onal Sector Stationary Source

Distillate Fuel Consumption

Sector Distillate Fuel Type % of Total Consumption



# from Stationary Sources

Commercial No. 1 Distillate Fuel Oil 80

No. 2 Distillate Fuel Oil 100

No. 2 Distillate/Ultra

- Low, Low, and High Sulfur Diesel 0 a



# No. 4 Distillate Fuel Oil 100

a 

# A very small portion of total commercial/institutiona l diesel is actually consumed by point sources (SCC 203001xx).



# c. Non-Fuel Energy Consumption

Some Industrial sector energy is consumed for non-f uel purposes. For example, natural gas is used as a feedstock

in chemical manufacturing plants and to make nitrog enous fertilizer, and LPG is used to create interme diate products

that are made into plastics. To estimate the volum e of fuel that is associated with ICI combustion, i t is necessary to

subtract the volume of fuel consumption for non-ene rgy uses from the volume of total fuel consumption. The EPA’s

State Inventory Tool (SIT) provides national default s representing the percentage of total Industrial f uel consumption

from non-energy uses. These default values have an additional limitation beyond their lack of geograph ic detail -

they represent the EIA’s definition of the Industri al sector, which includes fuel use that is accounte d for in other

inventory source categories (e.g., Farm, Mining, Con struction, and Commercial sectors fuel use that is accounted for

in the nonroad inventory). Because of these limita tions, TranSystems used regional non-fuel use percen tages

computed from energy consumption data from the EIA’ s 2006 Manufacturing Energy Consumption Survey (MECS)

for all fuel types (EIA, 2009c).

There are two reasons why MECS provides a more repre sentative data set for use in this project: (1) ME CS

provides data specific to the region of interest; a nd (2) MECS focuses solely on the Manufacturing sec tor. The latter

# January 2012



# 23 Final Report 

# characteristic is particularly important for fuel t ypes which consume significant amounts of non-Manuf acturing sector

energy that is already included elsewhere (e.g., di stillate fuel used by the Construction sector, whic h is included in

the nonroad inventory). The MECS non-fuel consumpti on data treat coal that is used to produce coke as a feedstock

(Lorenz, 2009). However, available data indicate t hat only four of the SESARM states produce coke (Al abama,

Kentucky, Virginia, West Virginia; EIA, 2008a) and coke combustion is not included in the area source emissions

inventory. Because of this, TranSystems estimated t he percent energy consumption from non-fuel use for SESARM

states without coke plants by subtracting the coal used in the primary metals industrial subsector (NA ICS code 331*)

from the MECS coal dataset. More than 97 percent o f coking coal is ultimately consumed in this subsec tor (Lorenz,

2009). Table II-9 presents the non-fuel use percent ages by type of energy.

Table II-9. Industrial Sector Energy Consumption from Non-Fuel Uses

Energy Type 2006 MECS % Energy Consumption from Non

- Fuel Use

South 1 

# National

Residual 30% 20%

Distillate 12% 12%

Natural Gas 11% 7%

LPG/NGL 99% 97%

Coal (excludes coking coal) 9% 6%

Sources: EIA, 2009c and Lorenz, 2009.

1 

# All SESARM states are in the South region.



# d. Emission Factors

Table II-10 presents the criteria pollutant emission factors that TranSystems used in calculating ICI co mbustion area

source emissions. Except as noted below, all crite ria air pollutant emission factors are from an EPA database used

to prepare the 2008 nonpoint source NEI (Huntley, 2 009). 10 

# Wood combustion emission factors are from AP-42

(EPA, 2003b). Because there are no NH 3 

# emission factors for ICI fuel combustion available in the 2008 NEI

emission factor database, AP-42, or EPA’s WebFIRE, TranSystems used emission factors reported in an NH 3 

# emissions Emission Inventory Improvement Program (E IIP) guidance document (Pechan, 2004).

10 

# All criteria pollutant emission factors were roun ded to two decimal places.January 2012Final Report24Table II-10. Criteria Pollutant Emission Factors for ICI Combustion Area Source CategoriesSCCDescriptionEmissionFactor Units1VOCNOxCOSO2PM2.5-FILPM10-FILPM-CONNH32102001000Industrial Anthracite Coallb/ton0.390.639 * S%0.48 * A%1.1 * A%0.080.032102002000Industrial Bitum/Subbitum Coallb/ton0.0511538 * S%1.4121.040.032102004000Industrial Distillate Oillb/1000 gal0.2205142 * S%0.2511.30.82102005000Industrial Residual Oil lb/1000 gal 0.28 55 5 157 *S%4.67 * (1.12 *S% + 0.37)7.17 * (1.12 *S% + 0.37)1.5 0.82102006000Industrial Natural Gaslb/MMcf5.5100840.60.110.20.320.492102007000Industrial LPG2lb/1000 bbl21.93985022.390.4380.7971.2751.952102008000Industrial Wood3lb/MMBtu0.0170.220.60.0250.430.50.0170.00742102011000Industrial Kerosenelb/1000 gal0.1919.294.82142 * S%0.240.961.250.7712103001000Comm/Inst Anthracite Coallb/ton0.390.639 * S%0.48 * A%1.1 * A%0.08 * A%0.032103002000Comm/Inst Bitum/Subbitum Coallb/ton0.0511538 * S%1.4121.040.032103004000Comm/Inst Distillate Oillb/1000gal0.34205142 * S%0.831.081.30.82103005000Comm/Inst Residual Oil lb/1000 gal 1.13 55 5 157 *S%1.92 * (1.12 *S% + 0.37)5.17 * (1.12 *S% + 0.37)1.5 0.82103006000Comm/Inst Natural Gaslb/MMcf5.5100840.60.110.20.320.492103007000Comm/Inst LPGlb/1000 bbl21.93985022.390.4380.7971.2751.952103008000Comm/Inst Wood3lb/MMBtu0.0170.220.60.0250.430.50.0170.00542103011000Comm/Inst Kerosenelb/1000 gal0.3319.294.82142 * S%0.81.041.250.771Source: Unless otherwise noted, 2008 nonpoint source NEI (Huntley, 2009).Notes:1lb = pound; ton = short ton; gal = gallon; MMcf =million cubic feet; MMBtu = million British thermalunits; bbl = barrels; S = sulfur content; A = ashcontent2Emission factors from Commercial/Institutional LPG.3Emission factors fromAP-42, Section 1.6, Wood Residue Combustion in Boilers (EPA, 2003b).4Emission factor from Pechan, 2004 (converted fromlb/ton using 0.08 ton/MMBtu for Industrial sector and 0.0625 ton/MMBtu for Commercial sector).

# January 2012

Final Report 

# 25 

# With a few notable exceptions, the 2008 NEI emissio n factors are the same as those used for the 2002 N EI. 11 

# The

PM emission factors for natural gas and LPG combust ion are the major exceptions. Because the 2002 emi ssion

factors were deemed too high because of artifact fo rmation in the test method (method 202) during stac k testing,

EPA developed a set of SCC-specific adjustment fact ors to apply to the 2002 NEI to better reflect PM e missions from

these fuels. 12 

# In preparation for the 2008 NEI, EPA developed re vised natural gas PM emission factors by applying

these adjustment factors to the 2002 NEI emission f actors. Revised emission factors for LPG were comp uted by

applying appropriate conversion factors to the upda ted natural gas emission factors.

e. Coal Sulfur and Ash Content

For a recent ICI combustion area source inventory pr oject for the Central Regional Air Planning Associa tion

(CENRAP), TranSystems evaluated the reliability of v arious data sources for coal sulfur content to be u sed to

estimate emissions in that project. TranSystems eva luated five potential data sources:

1. 2002 CENRAP state point source inventories;

2. U.S. Geological Survey (USGS)’s U.S. Coal Quality D atabase;

3. Energy Information Administration (EIA)’s “Cost and Quality of Fuels for Electric Plants 2002 and 2003. ”

4. EIA’s “EIA-423 - Monthly Nonutility Fuel Receipts an d Fuel Quality Data, 2002;” and

5. EIA’s “Quarterly Coal Report, January–March 2003.”

TranSystems evaluated these coal sulfur content data sources with respect to two specific criteria iden tified in the

QAPP for this project: representativeness and accu racy. Based on these evaluations, TranSystems used the

average sulfur content data from EIA’s “Quarterly C oal Report” to estimate the sulfur content of both Industrial and

Commercial/Institutional sector bituminous/subbitum inous coal in each SESARM state (EIA, 2008b). Even though

this source does not report whether the coal is bit uminous/subbituminous or anthracite, it is appropri ate to treat the

values for this source as representative of bitumin ous/subbituminous coal because anthracite accounts for only a

very small proportion of coal consumption in SESARM states.

Due to the lack of available data for anthracite co al, TranSystems used the average ash content (13.38 percent) and

sulfur content (0.89 percent) from the 2002 NEI for the Industrial and Commercial/Institutional sector s. These

percentages are based on the composition of anthrac ite coal seams in Pennsylvania, where all anthracit e coal

imported by SESARM states originated in 2007 (EIA, 2008c). Tables II-11 and II-12 report the coal ash and/or sulfur

content values that were used in calculating ICI co mbustion area source emissions for the 2007 base ye ar inventory.

11 

# The 2002 NEI documentation provides citations to the AP-42 source for each emission factor.

12 

# These factors reduce PM emissions by more than 90 percent.

# January 2012

Final Report 

# 26 

# Table II-11. Bituminous/Subbituminous Coal Sulfur Content for 2007 IC I Combustion

State Industrial Coal 1



# Sulfur Content (%) Commercial/

Institutional Coal 2



# Sulfur Content (%)

Alabama 0.94 0.94

Florida 0.87 0.87

Georgia 0.95 0.95

Kentucky 0.89 0.89

Mississippi 2.01 2.01

South Carolina 1.10 1.10

North Carolina 0.90 0.90

Tennessee 1.21 1.21

Virginia 0.96 0.96

West Virginia 0.95 0.95

1 

# Reflects the average from coal received in 2007.

2 

# Assumes that coal burned in the Commercial/Institut ional sector has the same composition as coal

burned in the Industrial sector.



# Table II-12. Anthracite Coal Ash and Sulfur Content for 2007 ICI Combustion

State Industrial Commercial/Institutional

Ash Content



# (%) Sulfur Content (%) Ash Content



# (%) Sulfur Content (%)

Alabama 13.38 0.89 13.38 0.89

Florida 13.38 0.89 13.38 0.89

Georgia 13.38 0.89 13.38 0.89

Kentucky 13.38 0.89 13.38 0.89

Mississippi 13.38 0.89 13.38 0.89

South Carolina 13.38 0.89 13.38 0.89

North Carolina 13.38 0.89 13.38 0.89

Tennessee 13.38 0.89 13.38 0.89

Virginia 13.38 0.89 13.38 0.89

West Virginia 13.38 0.89 13.38 0.89

# January 2012

Final Report 

# 27 

# f. County Allocation Data

After computing state-level area source emissions u sing the data described above, the next step is to allocate these

emissions to individual counties. Separate allocat ion approaches were implemented for the Industrial and

Commercial/Institutional sectors. For Commercial/In stitutional sector source categories, the approach relies on

county employment data compiled from government sou rces. For Industrial sector source categories, the approach

utilizes county-level Industrial sector energy cons umption estimates developed in this effort.

Commercial/Institutional

Because SEDS data originate from EIA fuel sector-sp ecific surveys of energy suppliers, 13 

# TranSystems reviewed

these survey forms/instructions for further details on what SEDS considers Commercial sector use of ea ch fuel. This

review found that the surveys/guidance do not alway s provide further clarity. In addition, the EIA ha s admitted that

energy suppliers may use their own account classifi cations as well as EIA guidance in determining whet her a

particular account belongs in the Residential, Comm ercial, Industrial, or Transportation sector. The on ly source of

NAICS-code based EIA definitions of the Commercial energy sector is a “rough crosswalk” between Commer cial

building types and NAICS codes developed for EIA’s Commercial Building Energy Consumption Survey (CBEC S).

With the exception of NAICS code 814 (Private House holds), this crosswalk links all NAICS codes betwee n 42 and

92 with Commercial building energy consumption. Em ployment data for the CBECS-identified NAICS codes (42

though 92 with exception of 814) were used to alloc ate SEDS energy consumption data to individual coun ties.

TranSystems used private sector 2006 employment data from County Business Patterns (CBP) and public sector

2006 employment data from the Census of Governments (Census, 2009a; and Census, 2009b) because these d ata

were already compiled in support of the 2008 NEI (y ear-to-year changes in county employment proportion s are

expected to be minimal).

Industrial

Unlike the Commercial sector, documentation provide s a clear listing of the NAICS codes associated wit h SEDS

Industrial energy consumption data: “the industria l sector encompasses the following types of activit y: Manufacturing (NAICS codes 31–33); Agriculture, Fore stry, Fishing and Hunting (NAICS code 11); Mining, i ncluding

Oil and Gas Extraction (NAICS code 21); and Constru ction (NAICS code 23).” As noted earlier, a portio n of Industrial

sector consumption (Agriculture, Mining and Constru ction) is already accounted for in other emission i nventory

sectors and was removed. Therefore, TranSystems did not expand the list of NAICS codes used to represen t the

area source Industrial fuel combustion category bey ond the Manufacturing sector NAICS codes (31-33).

Employment-based county allocation methods lead to overrepresentation of energy consumption in countie s with

sectors that have high employment but low energy in tensities (measured on a Btu per employee basis), a nd viceversa. Given that Manufacturing sectors have much greater energy intensity variability than Commercia l/Institutional

sectors, TranSystems utilized energy use per employe e values by NAICS code to improve upon the employme ntbased county allocation approach used in the 2008 N EI for the Industrial fuel combustion category. Thi s procedure

relied on 2007 national energy consumption data by NAICS code as reported by EIA in Annual Energy Outlook (EIA,

2009d). Energy intensity values were computed by d ividing these Btu-based energy consumption estimate s by

NAICS code-level 2007 national employment data. The resulting intensity values were then multiplied by

county/NAICS code-level employment estimates from C BP to estimate total county energy consumption by N AICS

code. These values were then summed for the approp riate Industrial fuel combustion NAICS codes. The resulting

county-level total Industrial energy consumption es timates were used to apportion state-level area sou rce Industrial

fuel combustion emissions to each county.

13 

# For natural gas, for example – EIA-176 “Annual Re port of Natural and Supplemental Gas Supply and Dis position.”

# January 2012

Final Report 

# 28 

# Estimation of Withheld Employment Data

Due to concerns with releasing confidential busines s information, the CBP withholds values for a given county/NAICS

code if it would be possible to identify individual businesses from these values. In such cases, the CBP reports a

letter code, representing a particular employment s ize range. TranSystems used the following procedure to estimate

data for withheld counties/NAICS codes.

1. County-level employment for counties with reported values are totaled by state for the applicable NAIC S code.

2. Value from step 1 is subtracted from the state empl oyment value for the NAICS code.

3. Each of the withheld counties is assigned an initia l employment estimate reflecting the midpoint of th e CBP

range code (e.g., code A, which reflects 1-19 emplo yees, is assigned an estimate of 10 employees).

4. The initial employment estimates from step 3 are the n summed to the state level.

5. The value from step 2 is divided by the value from s tep 4 to yield an adjustment factor to apply to the initial

employment estimates to yield employment values tha t will sum to the state employment total for the ap plicable

NAICS code.

6. The final county-level employment values are estimat ed by multiplying the initial employment estimates from

step 3 by the step 5 adjustment factors.

Example: NAICS 31-33 (Manufacturing) in Maine

fipsstate fipscty naics empflag emp

23 001 31---- 6,774

23 003 31---- 3,124

23 005 31---- 10,333

23 007 31---- 1,786

23 009 31---- 1,954

23 011 31---- 2,535

23 013 31---- 1,418

23 015 31---- F 0

23 017 31---- 2,888

23 019 31---- 4,522

23 021 31---- 948

23 023 31---- I 0

23 025 31---- 4,322

23 027 31---- 1,434

23 029 31---- 1,014

23 031 31---- 9,749



# 1. The total of employees not including counties 015 an d 023 is 52,801.

2. The state-level CBP reports 59,322 employees in NAIC S 31—the difference is 6,521.

3. County 015 is given a midpoint of 1,750 (since rang e code F is 1,000-2,499) and County 023 is given a m idpoint

of 17,500.

4. State total for these two counties is 19,250.

5. 6,521/19,250 = 0.33875.

The final employment estimate for county 015 is 1,75 0 * 0.33875 = 593. The county 023 final employment estimate

is computed as 17,500 * 0.33875 = 5,928.

# January 2012

Final Report 

# 29 

# 3. Estimation of Area Source Emissions from Residential Wood Combus tion

Residential wood combustion was calculated using th e EPA’s Residential Wood Combustion (RWC) Tool. The tool

uses the following equation to estimate RWC emissio ns:

Emissions = (Number of wood-burning appliances) x (Cords of wood burned per appliance) x (Density of

wood burned) x (Emission factor)

A review of the spatial distribution of SESARM regi on PM 2.5 

# emissions from the tool indicated much higher emis sions

in urbanized areas than rural areas. Although ther e is reason to expect some correlation between the number of

occupied housing units and residential wood combust ion emissions, this correlation would be expected t o be fairly

weak because of at least two factors. The first fac tor is that housing units in urbanized areas genera lly have greater

access to natural gas as a heating fuel, and theref ore, would be expected to have a greater penetratio n of natural

gas fireplaces than rural areas. The second factor is that the access to inexpensive wood supplies wou ld be

expected to be much greater in rural areas (and rel ated to this, the proportion of housing units with wood-burning

appliances that are used as primary heating units – i.e., woodstoves, outdoor hydronic heaters, pellet stoves – would

also be expected to be greater in rural areas). Re view of several wood consumption surveys, including the latest

survey from Minnesota, also showed a clear trend in households in urbanized areas consuming less wood than their

counterparts in rural areas.

Based on this review, SESARM, with primary assistan ce from Tracy Anderson of the Alabama Department of

Environmental Management, examined the EPA Tool’s de fault assumptions for the first two variables in th e RWC

emissions estimation equation. The following descri bes the specific refinements that SESARM incorporat ed into a

revised RWC Tool for these two variables.

Number of Wood-Burning Appliances

SESARM incorporated updates to the estimated number of the following types of wood-burning appliances:

• Fireplaces;

• Fireplace Insert Uncertified;

• Fireplace Insert EPA Certified Catalytic;

• Fireplace Insert EPA Certified Non-catalytic;

• Woodstove Uncertified;

• Woodstove EPA Certified Catalytic;

• Woodstove EPA Certified Non-catalytic; and

• Fireplaces Burning Wax Logs.

For these equipment types, the EPA’s RWC tool estima tes the number of wood-burning appliances in each c ounty by

multiplying the county’s number of occupied housing units by an appropriate wood-burning appliance pro file.

Where possible, SESARM first updated the occupied h ousing unit estimates in the Tool. The Tool estimate s the

number of occupied housing units by multiplying eac h county’s total number of housing units in 2007, a s reported by

the U.S. Census Bureau, by the county-level occupan cy rate in 2000 (last year of occupancy rate data a vailable from

the Census). For select counties (primarily those w ith large populations), the Census’ American Commun ity Survey

(ACS) reports estimates of the 2007 year number of occupied housing units. Several states use the ACS data and

indicated a preference for its use. Therefore, SESA RM updated the EPA tool to use the ACS’ housing uni t estimates

for counties where these data were available.

A second type of update involved revisions to the w ood-burning appliance profiles. Appliance profiles represent the

fraction of occupied housing units that have each o f the wood-burning appliances listed above. The app liance

profiles were developed from the number of wood bur ning appliances and number of occupied housing unit s data

# January 2012

Final Report 

# 30 

# compiled from the U.S. Census Bureau’s "American Ho using Survey" (AHS). The RWC Tool applies appliance

profiles to one or more geographic locations. The T ool includes a set of Metropolitan Statistical Area (MSA)-specific

appliance profiles and regional default appliance p rofiles (Northeast, Midwest, South, and West). Bas ed on new

information gathered from these surveys, SESARM cal culated 12 additional appliance profiles to better characterize

the wood-burning appliance population. These profil es are as follows:

1) A default urban appliance profile based on national urban values reported by the 2005 National AHS,

2) "Sub-MSA" area profiles for each of the following MSAs:

a. Birmingham, AL;

b. Miami-Dade County, FL;

c. Urban Atlanta, GA;

d. Kenton County, KY;

e. De Soto County, MS;

f. Gaston County, NC;

g. Mecklenburg County, NC;

h. York County, SC;

i. Shelby County, TN;

j. Fairfax County, VA; and

k. Urban Norfolk-Virginia Beach-Newport News area, VA.

These sub-MSA appliance profiles were developed usin g the “sub-area” sections of the original Metropoli tan Areas

AHS used in the RWC tool. In keeping with EPA’s MS A appliance profile assignment approach, SESARM ass igned

the sub-MSA profiles only to the counties to which they applied.

SESARM developed a default urban appliance profile in an attempt to better characterize wood-burning e quipment

populations in urbanized areas for which the AHS do es not report MSA-specific data. This profile refle cts national

average wood-burning appliance information from the 2005 National AHS. The next step was to develop a set of

criteria for determining what counties should be as signed the applicable regional average appliance pr ofile (South),

and which would be assigned the new national urban appliance profile. Figure 1 shows the decision tre e that

SESEARM developed to assign each of these two appli ance profiles.

# January 2012

Final Report 

# 31 

# Figure 1. Decision Tree for Assigning Regional Ave rage (Default) or National Urban

Appliance Profile Was the County/City

considered urban in the

2000 Census?

No.

Are the number of tracts

>1000 people/mile 2 

# less than

or equal to 5?

Yes.

Use Default Appliance

Profile. No.

Is Calculated Urban Fraction

greater than or equal to

0.80?

No.

Use Default Appliance

Profile. Yes.

Is 2010 County/City

Population Density greater

than 200 people/mile 2 

# ?

Yes.

Where there is not a Survey

Appliance Profile use the

Urban Appliance Profile.

No.

Use Default Appliance

Profile. Yes.

Where there is not a Survey

Appliance Profile use the

Urban Appliance Profile.

# January 2012

Final Report 

# 32 

# The above does not address the estimated count of th e following wood-burning appliance types:

• Pellet stoves;

• Indoor furnaces; and

• Hydronic heaters (also known as outdoor wood boiler s).

The estimates for these equipment types are hard-cod ed into the RWC Tool. After review of the EPA’s app liance

count estimation methods for these units, SESARM de cided that the estimates for these appliances shoul d also be

updated.

In the case of pellet stoves and hydronic heaters, the RWC Tool allocates regional (pellet stoves) or s tate-level

(hydronic heater) counts of each appliance type. Th e RWC Tool utilizes estimates of the number of each type of

equipment as calculated from cumulative sales data. The Tool then allocates these regional/state esti mates to

counties based on the proportion of regional/state number of woodstoves in each county. Because SESAR M’s

revised RWC Tool includes updated county-level woods tove population estimates, consistency with EPA’s

methodology requires re-allocating the estimated nu mber of regional/state pellet stoves and hydronic h eaters to each

county using the updated woodstove data incorporate d into the revised Tool.

The RWC Tool estimates the number of wood-burning ind oor furnaces by multiplying the estimated number of

woodstoves in each county by a factor. The EPA calc ulated this factor (0.53) from data on the number o f

woodstoves and indoor furnaces used for main heatin g in climate zones 1-3. To be consistent with the R WC Tool

methods for estimating indoor furnaces, SESARM upda ted the indoor furnace appliance counts by multiply ing the

revised number of woodstoves in each county by the 0.53 factor.

Cords of Wood Burned per Appliance

SESARM also incorporated new burn rate profiles tha t characterize the amount of wood burned in each ty pe of

appliance. As with the appliance profiles, burn ra te profiles can be assigned to one or more geograph ical areas. The

EPA’s RWC Tool included burn rate profiles that were developed and refined by EPA using survey data fro m the U.S.

Forest Service’s North Central region as the startin g point. The EPA adjusted these data based on the ratio of

energy consumption in the surveyed climate to energ y consumption in other areas of the country. For ex ample, if the

energy consumption in climate zone 5 (the warmest c limate zone) was half of the energy consumption in climate

zone 1 (the surveyed climate zone), burn rates in c limate zone 5 were estimated to be 50 percent of th e burn rates in

climate zone 1. The energy consumption data for the se adjustments was obtained from the Energy Informa tion

Administration (EIA)'s 2005 Residential Energy Cons umption Survey (RECS).

SESARM compiled 2005 RECS data to refine the EPA’s burn rates, by computing the average cords of wood burned

per household for each of three categories: Rural, Urban (sum of cities, towns, and suburbs), and Tota l. SESARM

then calculated two ratios: Rural to Total wood con sumption per household (1.563); and Urban to Total w ood

consumption per household (0.537). These ratios wer e then applied to the existing burn rate profiles t o create new

Rural and Urban burn rate profiles for each of the SESARM region climate zones—2, 3, 4, and 5. After the

appropriate calculations were performed the new bur n rate profiles were developed by adding either an “r” for Rural

or “u” for urban to the original RWC tool default b urn rate profile number. They are as follows:

1. Climate zone 2 : Nu and Nr

2. Climate zone 3 : 3Au and 3Ar

3. Climate zone 4 : 4u and 4r

4. Climate zone 5 : 5u and 5r

The next step in refining the burn rate information was to identify the criteria for assigning the Rura l, Urban, and

overall average burn rates (the original tool burn rate for a given climate zone) to each county withi n a climate zone.

SESEARM developed these criteria, which are represe nted in Figure 2.

# January 2012

Final Report 

# 33 

# After implementing the appliance profile and burn r ate refinements, SESARM developed emission summary

comparisons of EPA’s default RWC Tool versus the Tool updated by ADEM. These comparisons were submitted for

State//Local agency review and comment. The follow ing identify the revisions that were implemented ba sed on

comments supplied by S/L agencies:

• West Virginia revised the burn rate profiles in the following counties:

o Berkeley – from default to urban;

o Fayette – from rural to default; and

o Jefferson – from rural to default.

It should also be noted that Shelby County, Tennesse e directed SESARM to utilize Local agency RWC emiss ions in

place of the RWC Tool emissions.

Figure 2. Decision Tree for Assigning Average (Def ault), Urban, or Rural Burn Profiles

Was the County/City considered urban in the 2000 Ce nsus?

No.

Is Calculated Urban fraction less than 0.50?

No.

Are the number of tracts >1000 people/mile 2 

# equal to zero?

No.

Is Calculated Urban fraction greater than or equal to 0.80?

No.

Is 2010 County Population

Density >= 200 people/mile 2 

# ?

No.

Use Default Burn Rate. Yes.

Are the number of tracts >1000

people/mile 2 

# more than five?

Yes.

Use Urban Burn Rate. No.

Use Default Burn Rate. Yes.

Use Urban Burn Rate. Yes.

Is Appliance Profile = 39?

Yes.

Use Default Burn Rate.

No.

Use Rural Burn Rate. Yes.

Is 2010 County Population Density >=

200 and has 1 or more tracts>=

1000people/mile2?

Yes.

Use Default Burn Rate.

No.

Use Rural Burn rate. Yes.

Use Urban Burn Rate.

# January 2012

Final Report 

# 34 

# 4. Estimation of Area Source Emissions from Gasoline Service Stations/Stage I

TranSystems estimated stage I gasoline service stati on emissions using the NEI methodology referenced i n

Table II-2. To improve emission estimates, TranSystem s prepared a proposed set of key Stage I gasoline s ervice

station emission calculation parameter values for r eview by S/L agencies: (a) county-level gasoline t hroughput

values; (b) emission control parameter values; and (c) county/month-level Reid vapor pressure (RVP) va lues.

TranSystems specifically requested that agencies pro vide any updates they have to these values, includi ng updates

to the following control information: (a) filling technologies used (splash, submerged, and balanced submerged);

(b) the rule effectiveness of S/L requirements for submerged and/or balanced submerged filling; (c) th e rule

penetration (RP) for submerged and/or balanced subm erged filling; and (d) the control efficiency of ba lanced

submerged filling. The RP value represents the prop ortion of throughput that is filled using submerged /balanced

submerged filling, while the remaining proportion i s assumed to be splash filling. In keeping with pa st NEI practice,

the default rule effectiveness assumption was 100 p ercent (rule effectiveness is an adjustment to refl ect any

assumed non-compliance with the requirements of a r egulation). The default control efficiency for bala nced

submerged filling was 90 percent for all SESARM cou nties (control efficiency is the percentage of a so urce

category's emissions that is controlled by a contro l device). There is no control efficiency for subme rged filling

because the emission reduction effects of submerged filling are accounted for in the emission estimati on equation

(via a submerged-filling specific saturation factor ) rather than a post-emission estimation adjustment

.

TranSystems reviewed all updated parameter values su pplied by S/L agencies, provided follow-up question s/data

requests to ensure the completeness and validity of the data, and incorporated any updated Stage I emi ssion

calculation parameter values provided by agencies. TranSystems prepared revised base year stage I gaso line

service station VOC emission estimates using the ag ency-supplied values and provided S/L agencies with

spreadsheets comparing the original and revised emi ssion estimates. TranSystems updated the draft revi sed

emission estimates to reflect S/L agency comments, and incorporated the final revised Stage I estimate s into the

revised final stationary area source inventory.



# C. INVENTORY SUPPLEMENTATION/FINAL DATA MERGING

As directed by S/L agencies, TranSystems supplement ed 2007 S/L agency supplied emissions data (when su pplied)

and TranSystems default emissions data with emission s data from the 2002 nonpoint source NEI, or in the case of

Georgia, the State’s 2005 Consolidated Emissions Re porting Rule (CERR) submittal. To assist agencies t hat

supplied S/L emissions data, TranSystems compiled a list of SCC/pollutant combinations in the S/L area’ s portion of

the 2002 nonpoint source NEI that did not match to combinations in either the S/L agency inventory or TranSystems’

default inventory. This list was documented in an E xcel worksheet and transmitted along with a request for agencies

to identify whether each combination’s emissions sh ould be carried forward or grown to 2007 using EGAS growth

factors. TranSystems contacted agencies with any ne cessary follow-up questions to clarify guidance on the NEI

supplementation procedure.

To assist agencies that did not supply their own emi ssions data, TranSystems compiled a list of SCC/poll utant

combinations in the state’s portion of the 2002 non point source NEI that did not match to combinations in

TranSystems default inventory. These lists were docu mented in an Excel workbook, which also contained a

worksheet identifying associated inventory suppleme ntation questions (e.g., “the 2002 NEI reports VOC emissions

under Dry Cleaning/Perchloroethylene SCCs—TranSystem s default inventory does not include VOC emissions for

this SCC because perchloroethylene is no longer con sidered a VOC by EPA. Please confirm that VOC emis sions

from these SCCs should not be carried forward/grown ”). After reviewing state agency responses to thes e data

merging questions, TranSystems contacted agencies wi th follow-up questions as necessary to clarify stat e guidance.

# January 2012

Final Report 

# 35 

# Table II-13 displays the SCC/pollutant combinations for which 2002 nonpoint source NEI emissions were c arried

forward or grown to 2007 using growth factors from EGAS. 14 

# Further documenting the data merging procedures ar e

NIF EM table records and the SCC/county-level emissi on summaries that display a data source code for ea ch record.

Table II-14 presents the data source codes used to d ocument the source of each area source emission rec ord. The

compiled inventory was converted into EPA’s NIF 3.0 nonpoint source file format. 15

14 

# Note that for some SCCs, EGAS did not provide growt h factors. In these cases, Pechan used underlying EGAS 5.0

information (i.e., the EGAS Version 5.0 SCC-to-grow th indicator crosswalk and economic output data fro m version 5.5 of the

Regional Economic Models, Inc. [REMI] model) to dev elop growth factors.

15 

# Pechan removed throughput data when 2002 nonpoint s ource NEI data were carried forward,January 2012Final Report36Table II-13. Summary of Data Carried Forward/GrownFrom 2002 NEISourceClassification CodeSource Classification Code DescriptionAlabamaFloridaGeorgia1KentuckyRest ofStateMississippiSouthCarolinaTennessee-Rest ofStateVirginiaWestVirginia2275085000 Aircraft/Unpaved Airstrips/TotalEGAS EGAS2275900000 Aircraft/Refueling: All Fuels/All Processes ** (Use 25-01-080-xxx) EGAS2301030000 Chemical Manufacturing/Process Emissionsfrom Pharmaceutical Manuf/TotalCarry EGAS EGASCarry Carry Carry2301040000 Chemical Manufacturing/Fugitive Emissions from Synthetic Organic Chem Manuf/Total Carry EGAS Carry Carry2302050000 Food & Kindred Products/Bakery Products/TotalEGAS EGAS EGAS Carry EGAS Carry2302070005 Food & Kindred Products/Fermentation/Beverages/WineriesEGAS2302070010 Food & Kindred Products/Fermentation/Beverages/Distilleries EGAS2305070000 Mineral Processes/Concrete, Gypsum, Plaster Products/TotalCarry2306000000 Petroleum Refining/All Processes/TotalEGASCarry2306010000 Petroleum Refining/Asphalt Paving/Roofing Materials/TotalCarry2307060000 Wood Products/Misc Wood Products/TotalCarry2308000000 Rubber/Plastics/All Processes/TotalCarryCarry2309000000 Fabricated Metals/All Processes/TotalCarry2309100010 Fabricated Metals/Coating, Engraving, and Allied Services/ElectroplatingCarry2309100230 Fabricated Metals/Coating, Engraving, and Allied Services/Alkaline CleaningCarry2310000000 Oil & Gas Expl & Prod/All Processes/Total: All Processes EGAS Carry EGAS EGAS Carry CarryCarry2325000000 Mining &Quarrying/All Processes/TotalCarry EGAS EGAS EGAS EGAS Carry Carry2399000000 Industrial Processes: NEC/Industrial Processes: NEC/Total EGAS Carry EGAS EGASCarryCarry2401001010 Surface Coating/Architectural Coatings/Primers, Sealers, and UndercoatersCarry2401001050 Surface Coating/Architectural Coatings/All Other Architectural CategoriesCarry2401005600 Surface Coating/Auto Refinishing/PrimersCarry2401005700 Surface Coating/Auto Refinishing/Top CoatsCarry2440000000 Misc Industrial/All Processes/Total: AllSolvent TypesCarry EGASCarry2461800000 Misc Non-industrial: Commercial/Pesticide Applic.: All Processes/Total: All Solvent TypesEGAS EGAS EGAS EGAS Carry EGAS2461850000 Misc Non-indus: Consumer/Pesticide Application: Agricultural/All Processes EGAS EGAS Carry CarryJanuary 2012Final Report37SourceClassification CodeSource Classification Code DescriptionAlabamaFloridaGeorgia1KentuckyRest ofStateMississippiSouthCarolinaTennessee-Rest ofStateVirginiaWestVirginia2465800000 Misc Non-indus: Consumer/Pesticide Application/Total: All Solvent TypesEGASCarry2501000090 Petrol & Petrol Product Storage/All Storage Types: Breathing Loss/Distillate OilCarry2501050090 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/Distillate OilCarry2501050150 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/Jet NaphthaCarry2501050180 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/KeroseneCarry2501070000 Diesel Service Stations/Total: All Products/All Processes EGAS2501070051 Diesel Service Stations/Stage 1: Submerged FillingCarryCarry2501070052 Diesel Service Stations/Stage 1: SplashFillingCarry2501070101 Diesel Service Stations/Stage 2: Displacement Loss/UncontrolledCarry2501070103 Diesel Service Stations/Stage 2: SpillageCarry2501070201 Diesel Service Stations/Underground Tank: Breathing and Emptying CarryCarry2510000000 Organic Chemical Storage/All Storage Types: Breathing Loss/Total: All ProductsCarry2530000020 Bulk Materials Storage/All Storage Types/CementCarry2530000100 Bulk Materials Storage/All Storage Types/LimestoneCarry2530000120 Bulk Materials Storage/All Storage Types/SandCarry2530050000 Bulk Materials Storage/Bulk Stations/Terminals/Total: All ProductsCarry2601000000 On-site Incineration/All Categories/TotalCarry2601010000 On-site Incineration/Industrial/TotalEGAS EGAS2601020000 On-site Incineration/Commercial/Institutional/TotalEGAS EGAS EGAS Carry2620000000 Landfills/All Categories/TotalEGAS2620030000 Landfills/Municipal/TotalCarry EGASCarry Carry2630020000 Wastewater Treatment/Public Owned/TotalProcessedCarry2630020001 Wastewater Treatment/Public Owned/Flaring of GasesCarry2640000000 TSDFs/All TSDF Types/Total: All ProcessesEGAS EGAS EGAS EGAS Carry Carry2660000000Leaking Underground Storage Tanks/Leaking Underground Storage Tanks/Total: AllStorage TypesEGAS EGASCarry2801000000 Agric - Crops/TotalCarry EGAS Carry EGAS Carry CarryJanuary 2012Final Report38SourceClassification CodeSource Classification Code DescriptionAlabamaFloridaGeorgia1KentuckyRest ofStateMississippiSouthCarolinaTennessee-Rest ofStateVirginiaWestVirginia2801000003 Agric - Crops/TillingCarry EGAS EGAS Carry EGAS Carry Carry Carry2805001000Agric-Livestock/Beef cattle-finishingoperations on feedlots (drylots)/Dust Kicked-upby HoovesEGAS EGASEGAS Carry2810030000 Structure Fires/UnspecifiedCarry EGAS EGAS Carry EGAS Carry Carry2810050000 Motor Vehicle Fires/UnspecifiedEGAS EGASCarry2810060200 Cremation/Animals2830000000 Catastrophic/Accidental Releases/All Catastrophic/Accidental Releases/Total Carry2830001000 Catastrophic/Accidental Releases/Industrial Accidents/TotalCarry2841000040 Misc Repair Shops/Misc Repair Shops/Soldering OperationsCarry1TranSystems Default inventory for GA supplementedwith EGAS-grown emissions from Georgia’s 2005 CERRsubmission.

# January 2012

Final Report 

# 39 

# Table II-14. Area Source Inventory Data Source Codes

Code Description

P

- 07

- X

- NPT TranSystems default area source estimate

P

- 07

- X

- PT TranSystems default total source estimate adjusted for point source activity ( note that adjustment only



# occurred if emissions were reported in point source inventory).

N

- 02

- G 2002 nonpoint source NEI estimate grown using EGAS

N

- 02

- F 2002 nonpoint source NEI estimate carried forward ( no growth)

S

- 05

- G 2005 Georgia area source CERR submission estimate grown using EGAS

S

- 07

- X State agency

- supplied estimate

L

- 07

- X Local agency

- supplied estimate

L

- 07

- X

- VR Estimated from local agency VOC estimate and TranSystems default inventory derived ratio of



# pollutant emission factor to VOC emission factor.



# D. QA/QC PROCEDURES

In addition to the quality assurance procedures tha t TranSystems performed on the revised final 2007 st ationary area

source inventory (e.g., running EPA’s NIF QA/Content Checker program to check for referential integrity issues,

invalid entries, and out of typical range values), TranSystems quality assured all updates provided by S/L agencies to

ensure that they were correctly incorporated into t he final inventory, and reviewed the ratios of post -point source

subtraction emissions to pre-point source subtracti on emissions to confirm that these subtractions wer e properly

implemented.

# January 2012

Final Report 

# 40 

# III. 2007 NONROAD MOBILE SOURCE INVENTORY

The nonroad sector is comprised of nonroad engines i ncluded in EPA’s NONROAD model, as well as other en gines

not modeled in NONROAD, including aircraft, commerc ial marine vessels and locomotives. A 2007 nonroad sector

inventory was developed using the following general procedures:

• NONROAD model categories were based on the National Mobile Inventory Model (NMIM2008). SESARM

agencies were asked to review the latest 2007 NMIM County Database and provide revisions as needed to

the NMIM inputs.

• The aircraft category was based on EPA’s 2008 NEI. The 2008 estimates were backcast to 2007, and any

state comments were incorporated.

• The commercial marine vessel category was based on E PA’s 2008 NEI, adjusted to 2007, and

supplemented with any state emissions data.

• The locomotive category was based on draft Class I a nd Class II/III line haul emissions, as well as dra ft

railyard emissions developed by ERTAC. Passenger a nd commuter rail emissions were based on EPA’s

2002 NEI. State emission estimates were also inclu ded.

A more detailed description of how 2007 emissions e stimates for all nonroad categories were prepared i s provided

below.



# A. NONROAD MODEL CATEGORIES

NONROAD model categories include equipment such as recreational marine and land-based vehicles, farm,

construction and industrial machinery, and lawn and garden equipment. These equipment are powered by

compression-ignition engines, which are typically d iesel-fueled, as well as spark-ignition or gasoline -fueled engines.

Compressed natural gas (CNG) and LPG engines are al so included in the NONROAD model. Criteria polluta nt

emissions may not be reported for all SCCs for all counties in the SESARM region, and will depend on t he

geographic allocation methods used by the model, or state-specific allocation data.

NMIM2008 incorporates EPA’s latest NONROAD model (N ONROAD2008) released in April 2009, and reflects al l of

EPA’s final nonroad standards to date. TranSystems first distributed the 2007 year NMIM county-level d atabase

(NCD) to SESARM agencies for review and comment. Tr anSystems prepared a report to accompany nonroadrelated tables from the 2007 NCD providing instruct ions for agencies to provide any updates to these f iles that may

represent S/L/T improvements to the NMIM/NONROAD def aults (Pechan, 2009c). A summary of the tables

distributed and comments received from states is pr ovided in Table III-1.

# January 2012

Final Report 

# 41 Table III

- 1. Summary of 2007 NCD Tables and State Comments

NMIM Table Description Comments State(s)

County County

- specific variables Revised OzoneSeasonStartMonth and



# OzoneSeasonEndMonth AL, SC, VA

Update Barometric Pressure Jefferson C oun ty KY, VA

CountyYearMonthHour Hourly temps and relative humidity



# by month and county Revised temperatures and relative humidity using NC DC



# data and EPA-prescribed methodology VA

CountyNRFile External NONROAD data files Provided updates to SEASON.DAT file NC

Revised Underground Mining Cty Allocation File WV

CountyYear Additional external data files (mostly



# onroad related) None

CountyYearMonth Maps counti es to monthly fuel data Revised county/monthly gasoline profile assignments GA, KY, Jefferson C oun ty



# KY, NC, SC,

Davidson County TN, VA

Gasoline Gasoline fuel properties Revised/added gasoline fuel profiles GA, KY, Jefferson C oun ty



# KY, NC, SC, Davidson

Cty TN, VA

Diesel Diesel sulfur content Revised Diesel sulfur content Davidson C oun ty, TN

Natural Gas Natural gas content None



# Further descriptions of the state data provided and how they were evaluated and used is provided below.

CountyYearMonthHour Table

Virginia provided revised temperatures and relative humidity using National Climatic Data Center (NCDC ) data and

the EPA-prescribed methodology for stretching hourl y averages to capture daily minima and maxima value s.

CountyNR Table

North Carolina provided an updated SEASON.DAT file ( 37000.sea) that changed the seasonal profile assign ment for

North Carolina from the default Mid-Atlantic region to the Southeast region.

West Virginia provided an updated county allocation file for distributing activity and emissions relat ed to underground

mining equipment in their state. This revised count y distribution was based on 2007 Underground Coal P roduction

values as reported by the West Virginia’s Office of Miners' Health Safety and Training 2007 Co al Production by

County

.

CountyYearMonth, Gasoline, and Diesel Tables

Several states provided revised fuel profile assign ments by county, as reflected in changes to the Cou ntyYearMonth

table. In many cases, this also involved the creat ion of new gasoline profiles in the Gasoline table. The revisions

submitted primarily related to changes by month for Reid Vapor Pressure (RVP) values as well as gasoli ne sulfur

content. Updates to the oxygenated fuel data were provided for some states as well.

Some states also revised the diesel fuel sulfur con tent values for 2007. For regional consistency, unl ess the values

were based on actual testing that reflected the die sel sulfur content in use for an area, the NMIM def ault values of

1218 parts per million (ppm) for land-based equipme nt 1389 ppm for recreational marine were retained.

Once the inputs to NMIM/NONROAD were quality assure d, TranSystems ran NMIM to generate 2007 annual

emission estimates for all SESARM states for all no nroad SCCs. Emissions from aircraft ground support equipment

are now entirely addressed by the aircraft sector i nventory (see discussion under Section III.B of thi s report).

# January 2012

Final Report 

# 42 

# TranSystems removed emission estimates from the NMIM output for the airport GSE SCCs (i.e., SCCs 226500 8005,

2267008005, and 2270008005).



# B. AIRCRAFT

Airport-related emission estimates were developed f or the following SCCs listed in Table III-2.

Table III-2. Aircraft Source Classification Codes

Description SCC

Military Aircraft 2275001000

Commercial Aircraft 2275020000

General Aviation - Piston 2275050011

General Aviation - Turbine 2275050012

Air Taxi - Piston 2275060011

Air Taxi - Turbine 2275060012

Auxiliary Power Unit (APU) 2275070000

4-Stroke Gasoline GSE 2265008005

LPG GSE 2267008005

CNG GSE 2268008005

Diesel GSE 2270008005



# 2007 aircraft emissions were primarily based on EPA ’s 2008 NEI. The procedures and data for developing aircraft

emissions are described in further detail in EPA’s 2008 NEI documentation (ERG, 2009a).

For commercial aircraft, the emission estimation met hodology relied on airport and aircraft-specific la nding and takeoff (LTO) data, coupled with mode and aircraft-speci fic emission rates from the FAA’s Emission and Disp ersion

Modeling System (EDMS). Emissions for ground suppo rt equipment (GSE) and auxiliary power units (APUs)

associated with commercial air carriers were estima ted by EDMS, using operating time defaults based on the type of

service performed. LTO data for general aviation an d air taxi were obtained from FAA’s Terminal Area Fo recasts

(TAF) and 5010 Forms. This activity was assigned to j et and propeller-driven fractions, and fleet-averag e emission

factors were then applied. Finally, military aircr aft activity at civilian and commercial airports wa s obtained by EPA

from FAA’s TAF, and these emissions (with a few note d exceptions) were largely included in the 2007 SEM AP.

Unless provided by a state or local agency (e.g., G eorgia, North Carolina, and Virginia), military air craft activity and

emissions occurring at military facility bases are not accounted for in the SEMAP inventory.

The 2008 emissions and LTO data were back-cast to 20 07 using approach operations by airport and aircraf t type

compiled from the FAA’s Air Traffic Activity Data S ystem (ATADS) (FAA, 2010). The airport-level LTOs we re

assigned to counties and summed for the county. For counties with aircraft emissions without a county match in

ATADS, state average growth factors were calculated and applied. The county-level growth factors are n ot

presented in this report, but could be provided to SESARM if requested. The 2007 to 2008 growth factor s were

developed for each of the six airport source catego ries. Commercial aircraft, APU, and GSE categories relied on

growth factors calculated from commercial air carri er LTOs. General aviation and air taxi were grown u sing LTO data

reported for these specific aviation categories. M ilitary aircraft were held constant from 2008 to 20 07.

State-supplied data are summarized in Table III-3. Comments from Alabama, Georgia, and Davidson County

, Tennessee related to removing non-operational airpor ts, correcting county assignments for individual ai rports, or

# January 2012

Final Report 

# 43 

# updating emissions for specific commercial airports . Georgia, North Carolina, and Virginia submitted military aircraft

emissions for military bases in their state. In ad dition, North Carolina provided emissions for milit ary aircraft activity

at commercial airports, and also provided diesel GS E emissions associated with all military aircraft. Note that for

several North Carolina facilities, EPA had already reported diesel GSE emissions associated with comme rcial aircraft

activity, so state-provided diesel GSE emissions we re added to these existing EPA estimates at the SCC level.

Table III-3. Summary of State Updates to Aircraft Categor y Emissions

State/County SCC SCC Description Pollutants Comments

Alabama 2275050011 General Aviation Piston All Removed emissions for 1 non

- operational airport; 1 airport in



# GA incorrectly assigned to AL county

2275050012 General Aviation Turbine

Georgia 2275001000 Military Aircraft All Updated emissions for Dobbins Air Reserve Base

2275007000 Auxiliary Power Unit (APU) All Updated emissions for Dobbins Air Reserve Base

2275050011 General Aviation Piston All Made revisions to county assignments for 2 airports

2275050012 General Aviation Turbine

All SCCs See Table III

- 2 All Updated emissions for Atlanta Hartsfield Airport

North Carolina 2275001000 Military Aircraft All Added military aircraft emissions at military bases and c ivilian



# airports

2270008005 Diesel Airport GSE

Davidson C oun ty, TN 2275050011 General Aviation Piston All Removed emissions for 4 non

- operational airports; reassigned



# 1 airport from Davidson to Rutherford County

2275050012 General Aviation Turbine

2275020000 Commercial Aircraft All Updated emissions for Nashville International Airpo rt

2265008005 Gasoline Airport GSE All Updated emissions for Nashville International Airpo rt

2270008005 Diesel Airport GSE All Updated emissions for Nashville International Airpo rt

Virginia 2275001000 Military Aircraft All but PM



# 10, PM-2.5,

SO2 Added military aircraft emissions for 15 military b ases



# North Carolina and Georgia provided estimates for a ll needed pollutants, and Virginia provided estimat es for all

pollutants, with some exceptions for PM-10 and PM-2 .5. Where PM-10 was provided by Virginia for two f acilities, we

estimated PM-2.5 using a particle size multiplier o f 0.669, from Table “Military Aircraft Emission Facto rs” in Appendix

A to EPA 2008 NEI documentation (ERG, 2009a). PM a nd SO 2 

# emissions for the remaining military facilities in

Virginia were not estimated.



# C. COMMERCIAL MARINE VESSELS

Commercial marine vessel emissions are reported und er the following SCCs:

• 2280002100 – Diesel, In Port

• 2280002200 – Diesel, Underway

• 2280003100 – Residual, In Port

• 2280003200 – Residual, Underway

For the purpose of the NEI it was assumed that Categ ory 1 and 2 vessels typically use distillate fuels, while

Category 3 vessels primarily use residual blends. Category 3 engines are defined as having displaceme nt above

30 liters per cylinder.

# January 2012

Final Report 

# 44 

# 2007 CMV emissions were based largely on EPA’s 2008 NEI. For Category 1 and 2 engines, national diesel

emissions, based on national 2008 fuel sales, were split into near-shore port and underway components. Port

emissions were assigned to 150 largest ports using port traffic data per Waterborne Commerce of the U.S. For the

county allocation procedure, EPA developed a GIS sh ape file library based on Bureau of Transportation data to more

precisely assign port emissions to counties, and to better allocate underway emissions to line segment s/counties.

This represents an improvement to the spatial alloca tion procedure used for previous versions of the NE I.

2008 Category 3 CMV estimates were projected from a 2002 hourly modeling inventory developed by EPA’s Office of

Transportation and Air Quality (OTAQ), and aggregate d to an annual basis for the NEI. EPA developed Ca tegory 3

inventories for a total of 117 deep sea and inland ports, accounting for 4 different types of near-por t emissions,

including hotelling, maneuvering, reduced-speed zon e, and cruise mode. EPA spatially allocated emissi ons using

GIS shapefiles to specify the geographic locations for each type of near port emissions. Additional d etails concerning

the methodologies are described in EPA’s 2008 NEI d ocumentation (ERG, 2009b).

The 2008 CMV estimates were then adjusted to represe nt 2007. For Category 1 & 2 diesel commercial marin e

vessels, 2007 emissions were estimated by applying growth factors to the 2008 emissions. National 200 7 and 2008

emissions, by pollutant, were used to estimate the growth factors (EPA, 2008a). Emissions were adjust ed at a

national level because the surrogate data used to e stimate county-level emissions for the 2008 NEI act ually

represent year 2007. Table III-4 shows the growth f actors, by pollutant. The PM10-PRI and PM25-PRI gro wth factor

value was also used for NH 3



# .

Table III-4. Category 1 & CMV Growth Factors, by Pollutant

Pollutant Growth Factor

CO 1.009

NH 3 

# 1.045

NO

x 

# 1.016

PM10

- PRI 1.045

PM25

- PRI 1.045

SO 2 

# 1.110

VOC 1.008



# To estimate 2007 emissions for Category 3 residual c ommercial marine vessels, an annual average regiona l growth

rate was applied as a corresponding decrease to the 2008 NEI emissions (EPA, 2008b). A correspondence was

developed between the SESARM states and available r egional growth rates for the East Coast and Gulf Co ast.

Table III-5 contains this correspondence along with the growth factor. Counties in the State of Florida were assigned

to the two regions as appropriate.

# January 2012

Final Report 

# 45 

# Table III-5. Category 3 CMV Growth Factors, by State and SCC

FIPSST State SCC Region GF

01 AL 2280003100 Gulf Coast 0.955

01 AL 2280003200 Gulf Coast 0.955

12 FL 2280003100 Gulf Coast 0.955

12 FL 2280003200 Gulf Coast 0.955

12 FL 2280003100 East Coast 0.971

12 FL 2280003200 East Coast 0.971

13 GA 2280003100 East Coast 0.971

13 GA 2280003200 East Coast 0.971

21 KY 2280003100 East Coast 0.971

21 KY 2280003200 East Coast 0.971

28 MS 2280003100 Gulf Coast 0.955

28 MS 2280003200 Gulf Coast 0.955

37 NC 2280003100 East Coast 0.971

37 NC 2280003200 East Coast 0.971

45 SC 2280003100 East Coast 0.971

45 SC 2280003200 East Coast 0.971

47 TN 2280003100 East Coast 0.971

47 TN 2280003200 East Coast 0.971

51 VA 2280003100 East Coast 0.971

51 VA 2280003200 East Coast 0.971

54 WV 2280003100 East Coast 0.971

54 WV 2280003200 East Coast 0.971



# State provided data are listed in Table III-6. Sout h Carolina provided a county-level inventory for th e port of

Charleston for 2005. The 2005 estimates were grown to 2007 using Army Corps of Engineers data on total

commodity tonnage handled at the Port of Charleston (ACE, 2010). Davidson County provided a county-le vel CMV

inventory reported under the general SCC 2280000000 . Finally, Virginia also provided a military marine emissions

inventory, with the exclusion of Coast Guard Vessel s, since activity for these ships should be capture d by EPA’s

Category 1 & 2 inventory. The port and underway com ponents of Virginia’s marine inventory were assigne d to the

Residual, In Port and Residual, Underway SCCs, resp ectively. In counties where EPA had already report ed residual

port or underway emissions, state-provided military marine emissions were added to these existing EPA estimates at

the SCC level. Any necessary pollutant augmentatio n is described in Table III-6.January 2012Final Report46Table III-6. Summary of State Updates to Commercial Marine Category EmissionsState/CountySCCSCC DescriptionPollutantsCommentsAdditional RevisionsCharlestonCounty, SC2280002100Category 1&2 ResidualPortAll but NH3Removed NEI emissions and added SC supplied emissionsfor Charleston County, SC.NH3estimatedusingPM-10multiplier of 0.00477 (ERG, 2009b)2280002200Category 1&2 ResidualUnderwayAll but NH3NH3estimatedusing the ratio of 2008 NEI NH3/PM-10 emissionsfor the particular County/SCC.2280003100Category 3 Diesel PortAll but NH3NH3estimatedusingPM-10multiplier of 0.00477 (ERG, 2009b)2280003200Category 3 DieselUnderwayAll but NH3NH3estimatedusing the ratio of 2008 NEI NH3/PM-10 emissionsfor the particular County/SCC.DavidsonCounty, TN2280000000All Commercial MarineAll but PM-10, PM-25and NH3Removed all CMV NEI emissions for Davidson County,TNand added emissions supplied by the county.PM-10 estimated using emission factor (EPA, 2008a) and fuelconsumption (provided by Davidson County, TN).PM-25 estimated using PM-10 multiplier of 0.92 (EPA, 2008a).NH3estimated using PM-10 multiplier of 0.00477 (ERG,2009b)ShelbyCounty, TN2280002100Category 1&2 ResidualPortAllReplaced CMV NEI emissions for ShelbyCounty, TN with emissions supplied by the county.2280002200Category 1&2ResidualUnderwayAll but NH3Relied on EPA NEI NH3emissionsVirginia2280003100Category 3 Diesel PortAll but VOC, PM-25,and NH3Added military marine emissionsVOC estimated using HC multiplier of 1.053 (EPA, 2008a).PM-25 estimated using PM-10 multiplier of 0.92 (EPA, 2008a).NH3estimated using ratio of 2008 NEI NH3/PM-10 emissions forthe particular County/SCC.2280003200Category 3 DieselUnderwayAll but VOC, PM-25,and NH3VOC estimated using HC multiplier of 1.053 (EPA, 2008a).PM-25 estimated using PM-10 multiplier of 0.92 (EPA, 2008a).NH3estimated using ratio of 2008 NEI NH3/PM-10 emissions forthe particular County/SCC.

# January 2012

Final Report 

# 47 

# D. LOCOMOTIVES

Locomotive emissions are reported under the followi ng SCCs:

• 2285002006 – Diesel Class I Line Haul

• 2285002007 – Diesel Class II/III Line Haul

• 2285002008 – Diesel Passenger (Amtrak)

• 2285002009 – Diesel Commuter

• 2285002010 – Diesel Switchyard Locomotives

Class I line haul operations typically account for the majority of fuel consumed and emissions when pr eparing

locomotive inventories. As such, resources should be focused on developing emission estimates for the se

operations relative to other rail-related operation s. However, for some local areas, certain operatio ns related to

switchyard activity may also be important.

For Class I line-haul locomotives, emissions are nor mally calculated by multiplying the amount of fuel consumed in

the inventory area by pollutant-specific emission f actors. This calculation is performed for each rail road. The results

for each railroad are then summed to obtain the tot al Class I railroad emissions in the inventory area

.

For Class I line haul, TranSystems obtained 2007 emis sion estimates from the Eastern Regional Technical Advisory

Committee (ERTAC, 2010a). ERTAC used the Federal Ra ilroad Administration’s GIS data to construct a dat aset of

link-level million gross tons per mile (MGT). Next the Railroad Fuel Consumption Index (RFCI) value was calculated

for each railroad, which represents the number of G TM produced per gallon of diesel fuel. When applied to each

link’s GTM per year, link-based fuel consumption can be calculated. This methodology allows for a more accurate

reflection of how GTM are actually concentrated acr oss rail line route miles. Finally, the fuel consu med is multiplied

by the various emission factors derived for each Cl ass I rail line to determine link-level emissions f or each pollutant.

An important aspect is determining the fraction of locomotives that fall under each regulatory “Tier,” since each Tier

has an increasingly stringent emission rate for pol lutants of concern.

A limitation of the link-level MGT data maintained b y the FRA is that the data are proprietary and can o nly be publicly

released with the express permission of each Class I railroad. In addition, when the FRA coded the lin k-level MGT

data they did not provide a means for separating ou t individual MGT contributions for links that are op erated by

multiple railroad companies. As such, some assumpt ions were made for these contributions by ERTAC.

Class II/III line haul emissions were also develope d and distributed by ERTAC (ERTAC, 2010b). Limited

documentation has been developed to describe the pr ocedures used by ERTAC to develop this inventory. Generally,

fuel consumption for all Class II/III railroads was obtained from the American Shortline and Regional Railroad

Association and assigned to counties using route mi les by rail line within each county. An average fu el use factor

expressed in gallons per mile was then multiplied b y the route miles to estimate fuel consumption by r ailroad and by

county. Class II/III locomotives were all assumed to be uncontrolled with respect to emission rates u sed for

estimating pollutant emissions. Class II/III rail emissions represent calendar year 2008, and as such were back-cast

to 2007 using a surrogate growth indicator. A SESA RM regional growth factor of 1.438 was developed us ing 2007

and 2008 total distillate fuel sales/deliveries to railroad consumers which were obtained from the DOE Energy

Information Administration State Energy Data (DOE, 2009a).

Passenger and commuter rail line emissions from EPA ’s 2002 NEI were grown to 2007. For both categories , the

growth factor was developed using 2002 and 2007 pas senger/commuter fuel use data obtained from the DOE

Transportation Energy Data Book (DOE, 2009b). For p assenger rail operations, the growth factor value w as 0.732.

For commuter rail operations, a growth factor of 1.1 1 was used.

# January 2012

Final Report 

# 48 

# Finally, a switchyard inventory was completed by ERT AC on June 4, 2010 (ERTAC, 2010c). This inventory w as

compiled at a railyard level by ERTAC, but was summ ed to a county level for use in the SEMAP 2007 inve ntory. In

general, switcher emissions were estimated using to tal switcher fuel consumption available from each C lass I R-1

report allocated to railyards based on average dens ity code data reported by the Federal Railroad Admin istration.

Documentation describing the specific methodology a nd data sources used will be forthcoming from ERTAC

.

Some state data were provided for the locomotive ca tegory. These data are summarized in Table III-7. N orth

Carolina provided a statewide passenger rail invent ory for 2007. Davidson County provided a county le vel inventory

comprised of Class I line haul and switchyard activ ity, reported under the general SCC 2285000000. Sh elby County

provided an updated Class I line haul, passenger, a nd yard locomotive inventory for most pollutants. Any needed

pollutant augmentation is described in Table III-7.



# E. QA/QC PROCEDURES

TranSystems performed the following quality assuranc e procedures on the final 2007 nonroad sector inven tory.

For the NONROAD/NMIM categories, TranSystems quality assured all NCD updates provided by states to ensur e

consistency with the NCD formats, and for reasonabl eness. Where questions came up, we coordinated wit h the

appropriate S/L agency. Cross-checks were performe d to confirm that state-supplied revisions were cor rectly

incorporated into the NCD. TranSystems compared res ults with 2007 emission estimates prepared by EPA u sing a

prior version of the NCD. These comparisons were pe rformed to ensure that results changed as expected given the

updates made by specific states to the NMIM inputs.January 2012Final Report49Table III-7. Summary of State Updates to Locomotive Category EmissionsStateSCCSCC DescriptionPollutantsCommentsAdditional RevisionsNorth Carolina2285002008Line Haul Locomotives: PassengerTrains (Amtrak)All but NH3Replaced NEI passenger emissions withNC supplied emissionsNH3estimatedusing the ratio of2008 NEI NH3/PM-25 emissionsfor the particular County/SCC.2285002007Line Haul Locomotives: Class II/IIILocomotivesAllRemoved activity/emissions for several raillinesDavidson County, TN2285000000All Railroad All FuelsAll but PM-25and NH3Replaced ERTAC rail emissions withDavidson County supplied emissionsPM-25estimated using PM-10multiplier of 0.97 (EPA, 2008a).NH3estimated using ratio of 2008NEI NH3/PM-25 emissions for theparticular County/SCC.Shelby County, TN2285002006Line Haul Locomotives: Class IOperationsAll butPM-25 andNH3Replaced ERTACrail emissions withShelby County supplied emissionsRelied on ERTAC emissions formissing pollutants2285002008Line Haul Locomotives: PassengerTrains (Amtrak)All but NH3Relied on SEMAP defaultemissions for NH32285002010Yard LocomotivesAll

# January 2012

Final Report 

# 50 

# TranSystems compiled records for the SESARM region f rom EPA’s NEI for aircraft, CMV, and passenger/comm uter

rail, and obtained Class I and Class II/III line ha ul, and railyard emission estimates from ERTAC. Tra nSystems

performed and quality assured any needed adjustment s to year 2007 (i.e., correct application of growth or backcast

factors). Cross-checks were also performed to veri fy that state-supplied emission estimates were corr ectly

incorporated into the draft inventory. TranSystems also calculated missing pollutants for SCC-level st ate emission

estimates, where emission factors or emission ratio s were available.

Emission estimates were converted into EPA’s NIF3.0 as a final deliverable. For the NMIM categories, co mmercial

marine, and locomotive, separate database files wer e prepared for each subsector following EPA’s NIF3.0 nonpoint

format. Aircraft emission estimates were prepared in EPA’s NIF3.0 point source format. EPA’s NIF QA C hecker

program was then run on these final files, and any referential integrity issues and invalid codes were identified and

corrected. Finally, data source codes as described in Table III-8 were added to the NIF3.0 files to repr esent the

source of the SCC, county-level emissions data for the final inventory.

Table III-8. Data Source Codes Used for Revised Final 2007 Nonroad Mobile Emission Estimates

Code Description

P

- 07

- X TranSystems d efault

N

- 02

- G 2002 NEI grown

S

- 07

- X State s upplied

S

- 07

- X

- PS State supplied added to TranSystems d efault

S

- 05

- G State supplied 2005 grown

L

- 07

- X Local a gency s upplied

# January 2012

Final Report 

# 51 

# IV. EMISSIONS SUMMARIES

This section presents the emission summaries for the revised final 2007 stationary area and nonroad mob ile

emissions inventory for the SEMAP project. In addi tion to the summaries provided in this section, Tran Systems has

also provided SESARM with detailed county-level emi ssion summaries in Excel worksheets.



# A. STATIONARY AREA SOURCE EMISSIONS

Table IV-1 provides a summary of the final 2007 SESA RM area source emissions inventory by the four majo r area

source subsectors. Table IV-2 displays final area s ource emission estimates by state, as well as the p ercent

contribution of each state to total regional emissi ons. Similar summaries providing 2007 annual state -level emission

estimates for each major area source sector, as wel l as percent contributions by state, are shown in T ables IV-3

through IV-6.

Table IV-1. Final 2007 SESARM Area Source Emissions by Maj or Sector

Category Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Combustion 81,876 105,283 28,444 95,946 69,362 273,557 7,901

Solvents 712,961 24 4 0.1

Fugitive Dust 2,311,660 242,976

All Other 2,905 11,807 433,868 299,768 109,872 157,631 576,97 5

All Nonpoint 84,782 117,090 1,175,273 2,707,398 422,214 431,188 584,876

# January 2012

Final Report 

# 52 

# Table IV-2. Final 2007 Area Source Emission Estimates by S tate

State Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 431 3,940 79,030 349,981 41,587 15,152 62,426

Florida 11,203 13,014 296,131 340,693 55,515 43,381 33,940

Georgia 4,858 25,552 143,469 652,757 95,801 83,246 86,544

Kentucky 15,590 12,693 75,100 226,829 40,341 55,450 52,332

Mississippi 344 6,091 74,755 326,350 42,758 22,377 58,774

North Carolina 8,365 12,715 152,825 51,678 16,829 47,379 169,440

South Carolina 6,048 9,353 76,838 266,749 39,538 32,208 30,248

Tennessee 14,415 12,418 111,100 215,667 33,948 44,668 35,277

Virginia 17,022 17,740 133,935 176,265 39,034 63,838 43,038

West Virginia 6,504 3,574 32,089 100,429 16,862 23,490 12,858

Total SESARM 84,782 117,090 1,175,273 2,707,398 422,214 431,188 584,876

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 0.5 3.4 6.7 12.9 9.8 3.5 10.7

Florida 13.2 11.1 25.2 12.6 13.1 10.1 5.8

Georgia 5.7 21.8 12.2 24.1 22.7 19.3 14.8

Kentucky 18.4 10.8 6.4 8.4 9.6 12.9 8.9

Mississippi 0.4 5.2 6.4 12.1 10.1 5.2 10.0

North Carolina 9.9 10.9 13.0 1.9 4.0 11.0 29.0

South Carolina 7.1 8.0 6.5 9.9 9.4 7.5 5.2

Tennessee 17.0 10.6 9.5 8.0 8.0 10.4 6.0

Virginia 20.1 15.2 11.4 6.5 9.2 14.8 7.4

West Virginia 7.7 3.1 2.7 3.7 4.0 5.4 2.2

Total SESARM 100 100 100 100 100 100 100

# January 2012

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# 53 

# Table IV-3. Final 2007 Combustion Emission Estimates by Stat e

State Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 376 3,490 1,903 1,400 1,391 11,257 449

Florida 11,032 12,163 2,421 27,419 19,713 29,097 585

Georgia 4,528 23,648 2,751 14,118 14,092 59,474 1,851

Kentucky 15,250 11,287 3,892 13,006 8,573 31,102 670

Mississippi 206 5,274 1,238 1,074 1,043 9,933 307

North Carolina 8,090 11,534 4,313 4,795 4,394 29,963 910

South Carolina 5,900 8,480 1,743 10,510 7,926 18,699 427

Tennessee 14,058 10,853 2,929 12,756 2,521 25,816 833

Virginia 16,061 15,569 5,270 8,142 7,358 43,205 1,443

West Virginia 6,376 2,985 1,984 2,728 2,354 15,012 424

Total SESARM 81,876 105,283 28,444 95,946 69,362 273,557 7,901

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 0.5 3.3 6.7 1.5 2.0 4.1 5.7

Florida 13.5 11.6 8.5 28.6 28.4 10.6 7.4

Georgia 5.5 22.5 9.7 14.7 20.3 21.7 23.4

Kentucky 18.6 10.7 13.7 13.6 12.4 11.4 8.5

Mississippi 0.3 5.0 4.4 1.1 1.5 3.6 3.9

North Carolina 9.9 11.0 15.2 5.0 6.3 11.0 11.5

South Carolina 7.2 8.1 6.1 11.0 11.4 6.8 5.4

Tennessee 17.2 10.3 10.3 13.3 3.6 9.4 10.5

Virginia 19.6 14.8 18.5 8.5 10.6 15.8 18.3

West Virginia 7.8 2.8 7.0 2.8 3.4 5.5 5.4

Total SESARM 100 100 100 100 100 100 100

# January 2012

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# 54 

# Table IV-4. Final 2007 Solvent Emission Estimates by State

State Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 54,760

Florida 164,244

Georgia 86,349

Kentucky 45,697 1 1

Mississippi 42,797

North Carolina 113,623 0.1

South Carolina 38,952

Tennessee 63,279 22 4

Virginia 89,798

West Virginia 13,463

Total SESARM 712,961 24 4 0.1

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 7.7 0.0 0.0 0.0

Florida 23.0 0.0 0.0 0.0

Georgia 12.1 0.0 0.0 0.0

Kentucky 6.4 5.0 16.5 0.0

Mississippi 6.0 0.0 0.0 0.0

North Carolina 15.9 0.0 0.0 100.0

South Carolina 5.5 0.0 0.0 0.0

Tennessee 8.9 95.0 83.5 0.0

Virginia 12.6 0.0 0.0 0.0

West Virginia 1.9 0.0 0.0 0.0

Total SESARM 100 100 100 100

# January 2012

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# 55 

# Table IV-5. Final 2007 Fugitive Dust Emission Estimates by S tate

State Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 318,858 33,717

Florida 270,262 22,325

Georgia 580,492 62,104

Kentucky 184,551 19,979

Mississippi 301,642 32,897

North Carolina 37,467 3,722

South Carolina 235,508 23,304

Tennessee 176,850 19,521

Virginia 134,014 18,730

West Virginia 72,018 6,676

Total SESARM 2,311,660 242,976

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 13.8 13.9

Florida 11.7 9.2

Georgia 25.1 25.6

Kentucky 8.0 8.2

Mississippi 13.0 13.5

North Carolina 1.6 1.5

South Carolina 10.2 9.6

Tennessee 7.7 8.0

Virginia 5.8 7.7

West Virginia 3.1 2.7

Total SESARM 100 100

# January 2012

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# 56 

# Table IV-6. Final 2007 All Other Area Source Emission Esti mates by State

State Pollutant Emissions, TPY

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 56 450 22,368 29,724 6,480 3,895 61,977

Florida 171 851 129,465 43,012 13,477 14,285 33,355

Georgia 331 1,903 54,369 58,148 19,605 23,771 84,693

Kentucky 340 1,406 25,512 29,271 11,789 24,347 51,662

Mississippi 138 817 30,720 23,634 8,819 12,445 58,467

North Carolina 276 1,181 34,888 9,417 8,713 17,416 168,530

South Carolina 147 873 36,143 20,732 8,308 13,508 29,820

Tennessee 357 1,565 44,892 26,039 11,903 18,852 34,444

Virginia 961 2,172 38,867 34,109 12,946 20,633 41,594

West Virginia 128 589 16,643 25,683 7,833 8,478 12,433

Total SESARM 2,905 11,807 433,868 299,768 109,872 157,631 576,97 5

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM2.5-PRI CO NH 3



# Alabama 1.9 3.8 5.2 9.9 5.9 2.5 10.7

Florida 5.9 7.2 29.8 14.3 12.3 9.1 5.8

Georgia 11.4 16.1 12.5 19.4 17.8 15.1 14.7

Kentucky 11.7 11.9 5.9 9.8 10.7 15.4 9.0

Mississippi 4.8 6.9 7.1 7.9 8.0 7.9 10.1

North Carolina 9.5 10.0 8.0 3.1 7.9 11.0 29.2

South Carolina 5.1 7.4 8.3 6.9 7.6 8.6 5.2

Tennessee 12.3 13.3 10.3 8.7 10.8 12.0 6.0

Virginia 33.1 18.4 9.0 11.4 11.8 13.1 7.2

West Virginia 4.4 5.0 3.8 8.6 7.1 5.4 2.2

Total SESARM 100 100 100 100 100 100 100



# B. NONROAD MOBILE SOURCE EMISSIONS

Table IV-7 provides a summary of final 2007 nonroad mobile annual emissions by the four major nonroad s ubsectors

for the SESARM region. PM-10 and PM-2.5 emissions represent primary PM, and are reported as PM10-PRI, and

PM25-PRI. The commercial marine category is the mos t significant contributor regionally to SO 2 

# emissions.

Nonroad model categories account for the large majo rity of emissions for NO

x 

# , VOC, PM10-PRI, PM25-PRI, and CO.

Table IV-8 presents a summary of the final annual NO NROAD model emission estimates by state, as well as the

percent contribution of each state to total regiona l emissions. Similar summaries providing 2007 annu al state-level

emission estimates for aircraft, commercial marine, and locomotives, as well as the percent contributi ons, are shown

in Tables IV-9, IV-10, and IV-11, respectively.

Since development of the draft inventory, locomotiv e switchyard emissions developed by ERTAC have been added.

These emission estimates were developed at a railyar d level, and summed to the county level for the 200 7 SEMAP

inventory. As mentioned in Section III.D, we are p roviding an electronic file that provides emissions at a railyard

level, so that SESARM agencies can review the data that form the basis of the county-level estimates, and make any

needed revisions. In addition, for the aircraft ca tegory, EPA made some additions to the 2008 militar y aircraft NEI

that formed the basis of the initial draft SEMAP in ventory. As discussed in Section III.B, we are dis tributing an

# January 2012

Final Report 

# 57 

# electronic file showing additional emission records calculated by EPA for military aircraft by airport for the SESARM

region. Agencies should provide feedback as to whe ther these records should be added to their invento ry.

Table IV-7. Final 2007 SESARM Nonroad Source Emissions by Major Sector

Category Pollutant Emissions, tons per year

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# NONROAD Model 23,308 404,580 629,693 41,489 39,517 4,642,050 447

Aircraft 3,105 32,153 18,444 4,066 3,037 196,823 NA

Commercial Marine 33,715 162,801 4,516 7,869 7,462 28,726 86

Locomotive 2,178 155,025 8,285 5,085 4,693 21,633 67

All Nonroad 62,307 754,560 660,938 58,508 54,709 4,889,232 601



# Table IV-8. Final 2007 NONROAD Model Emission Estimates by State

State Pollutant Emissions, tons per year

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 1,483 26,695 49,956 2,806 2,665 316,138 30

Florida 6,714 109,218 193,974 11,543 10,986 1,431,4 64 134

Georgia 3,079 51,524 69,914 5,315 5,067 629,419 56

Kentucky 1,630 28,665 36,641 2,877 2,749 240,397 28

Mississippi 1,147 20,050 33,760 2,126 2,025 187,258 21

North Carolina 3,111 55,743 76,568 5,434 5,181 597, 360 58

South Carolina 1,522 26,742 42,293 2,661 2,534 328, 606 29

Tennessee 1,884 36,756 54,089 3,637 3,467 388,496 3 8

Virginia 2,329 41,658 55,164 4,132 3,937 416,303 45

West Virginia 410 7,529 17,333 957 905 106,610 9

Total SESARM 23,308 404,091 630,621 41,489 39,5 17 4,674,012 447

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 6.4 6.6 7.9 6.8 6.7 6.8 6.7

Florida 28.8 27.0 30.8 27.8 27.8 30.8 29.9

Georgia 13.2 12.7 11.1 12.8 12.8 13.6 12.6

Kentucky 7.0 7.1 5.8 6.9 7.0 5.2 6.2

Mississippi 4.9 5.0 5.4 5.1 5.1 4.0 4.7

North Carolina 13.3 13.8 12.2 13.1 13.1 12.9 13.0

South Carolina 6.5 6.6 6.7 6.4 6.4 7.1 6.6

Tennessee 8.1 9.1 8.6 8.8 8.8 8.4 8.4

Virginia 10.0 10.3 8.8 10.0 10.0 9.0 10.0

West Virginia 1.8 1.9 2.8 2.3 2.3 2.3 2.0

Total SESARM 100 100 100 100 100 100 100

# January 2012

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# 58 

# Table IV-9. Final 2007 Aircraft Emission Estimates by St ate

State Pollutant Emissions, tons per year

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO

Alabama 51 440 891 294 205 14,778

Florida 992 10,746 5,060 1,028 772 57,332

Georgia 608 4,909 2,771 433 346 28,082

Kentucky 219 2,257 918 204 154 11,555

Mississippi 26 219 665 168 117 8,520

North Carolina 370 3,499 2,487 521 423 22,482

South Carolina 68 586 930 210 149 11,117

Tennessee 354 4,054 1,623 292 227 16,318

Virginia 410 5,385 2,842 844 594 23,032

West Virginia 7 59 257 72 50 3,607

Total SESARM 3,105 32,153 18,444 4,066 3,037 1 96,823

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO

Alabama 1.6 1.4 4.8 7.2 6.8 7.5

Florida 32.0 33.4 27.4 25.3 25.4 29.1

Georgia 19.6 15.3 15.0 10.7 11.4 14.3

Kentucky 7.1 7.0 5.0 5.0 5.1 5.9

Mississippi 0.8 0.7 3.6 4.1 3.9 4.3

North Carolina 11.9 10.9 13.5 12.8 13.9 11.4

South Carolina 2.2 1.8 5.0 5.2 4.9 5.6

Tennessee 11.4 12.6 8.8 7.2 7.5 8.3

Virginia 13.2 16.7 15.4 20.8 19.6 11.7

West Virginia 0.2 0.2 1.4 1.8 1.6 1.8

Total SESARM 100 100 100 100 100 100

# January 2012

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# 59 

# Table IV-10. Final 2007 Commercial Marine Vessel Emiss ion Estimates by State

State Pollutant Emissions, tons per year

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 1,739 18,554 411 726 699 3,723 8

Florida 18,146 48,271 1,261 2,971 2,778 7,014 29

Georgia 2,044 10,582 257 476 456 1,845 5

Kentucky 1,015 15,726 338 576 558 3,009 11

Mississippi 1,784 18,119 401 710 683 3,368 10

North Carolina 1,846 4,233 109 222 209 670 2

South Carolina 1,289 1,946 109 138 123 220 1

Tennessee 731 7,565 765 502 469 2,082 4

Virginia 4,094 21,918 524 966 922 3,755 10

West Virginia 1,026 15,888 341 582 564 3,040 8

Total SESARM 33,715 162,801 4,516 7,869 7,462 28,72 6 86

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 5.2 11.4 9.1 9.2 9.4 13.0 9.4

Florida 53.8 29.7 27.9 37.8 37.2 24.4 33.3

Georgia 6.1 6.5 5.7 6.1 6.1 6.4 5.3

Kentucky 3.0 9.7 7.5 7.3 7.5 10.5 12.6

Mississippi 5.3 11.1 8.9 9.0 9.2 11.7 11.3

North Carolina 5.5 2.6 2.4 2.8 2.8 2.3 2.3

South Carolina 3.8 1.2 2.4 1.8 1.6 0.8 1.0

Tennessee 2.2 4.6 16.9 6.4 6.3 7.2 4.6

Virginia 12.1 13.5 11.6 12.3 12.4 13.1 11.5

West Virginia 3.0 9.8 7.6 7.4 7.6 10.6 8.8

Total SESARM 100 100 100 100 100 100 100

# January 2012

Final Report 

# 60 

# Table IV-11. Final 2007 Locomotive Emission Estimates by Sta te

State Pollutant Emissions, tons per year

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 196 17,899 972 598 552 2,542 8

Florida 175 11,625 592 356 332 1,505 5

Georgia 252 24,066 1,303 801 739 3,402 11

Kentucky 173 16,806 888 550 508 2,355 7

Mississippi 131 9,933 489 304 280 1,295 4

North Carolina 130 11,592 622 378 350 1,610 5

South Carolina 99 8,968 479 296 273 1,264 4

Tennessee 367 19,461 1,083 650 591 2,799 8

Virginia 444 21,639 1,180 728 678 3,066 9

West Virginia 212 13,037 677 423 389 1,796 6

Total SESARM 2,178 155,025 8,285 5,085 4,693 21,633 67

State Percentage of Regional Total

SO 2 

# NO

x 

# VOC PM10-PRI PM25-PRI CO NH 3



# Alabama 9.0 11.5 11.7 11.8 11.8 11.8 11.8

Florida 8.0 7.5 7.1 7.0 7.1 7.0 6.9

Georgia 11.6 15.5 15.7 15.7 15.7 15.7 15.8

Kentucky 8.0 10.8 10.7 10.8 10.8 10.9 10.9

Mississippi 6.0 6.4 5.9 6.0 6.0 6.0 6.0

North Carolina 6.0 7.5 7.5 7.4 7.5 7.4 7.5

South Carolina 4.6 5.8 5.8 5.8 5.8 5.8 5.8

Tennessee 16.8 12.6 13.1 12.8 12.6 12.9 12.5

Virginia 20.4 14.0 14.2 14.3 14.4 14.2 14.0

West Virginia 9.8 8.4 8.2 8.3 8.3 8.3 8.7

Total SESARM 100 100 100 100 100 100 100

# January 2012

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# 61 

# V. REFERENCES

ACE, 2010. U.S. Army Corps of Engineers, Navigati on Data Center, U.S. Waterways Data, Principal Port

commodity tonnage for 2005 and 2007, available at http://www.iwr.usace.army.mil/ndc/db/pport/dbf , accessed

on January 2010.

Census, 2009a. U.S. Census Bureau, 2006 County Business Patterns , U.S. Department of Commerce, accessed

from http://www.census.gov/epcd/cbp/index.html , March 2009.

Census, 2009b: U.S. Census Bureau, 2006 Census of Governments , U.S. Department of Commerce, accessed from

http://www.census.gov/govs/apes/historical_data_200 6.html , April 2009.

DOE, 2009a. U.S. Department of Energy, Energy Info rmation Administration, “Petroleum Navigator- Total Distillate

Sales/Deliveries to Railroad Consumers (Thousand Gal lons),”

http://tonto.eia.doe.gov/dnav/pet/pet_cons_821dst_d cu_nus_a.htm , December 2009.

DOE, 2009b. U.S. Department of Energy, Energy Effi ciency and Renewable Energy, “Transportation Energy Data

Book: Tables A.13 and A.15, http://cta.ornl.gov/data/appendix_a.shtml , 2009.

EIA, 2008a. Energy Information Administration, “Do mestic Distribution of U.S. Coal by Destination Sta te, Consumer,

Origin and Method of Transportation, 2007,” U.S. Dep artment of Energy, available from

http://www.eia.doe.gov/cneaf/coal/page/coaldistrib/ 2007/d_07state.pdf , issued December 2008.

EIA, 2008b:. Energy Information Administration, “Qu arterly Coal Report, October–December 2007,” DOE/EI A-0121

(2007/04Q), U.S. Department of Energy, available fr om

http://tonto.eia.doe.gov/FTPROOT/coal/qcr/0121074q.pdf , issued March 2008.

EIA, 2008c. Energy Information Administration, “Do mestic Distribution of U.S. Coal by Origin State, C onsumer,

Destination and Method of Transportation, 2007,” U.S . Department of Energy, available from

http://www.eia.doe.gov/cneaf/coal/page/coaldistrib/ 2007/o_07state.pdf , issued December 2008.

EIA, 2009a. Energy Information Administration, “St ate Energy Data System (SEDS): Consumption, Price, and

Expenditure Estimates,” U.S. Department of Energy, accessed from

http://www.eia.doe.gov/emeu/states/_seds.html , accessed December 2009.

EIA, 2009b. Energy Information Administration, “Fu el Oil and Kerosene Sales,” U.S. Department of Ener gy,

accessed from

http://www.eia.doe.gov/pub/oil_gas/petroleum/data_p ublications/fuel_oil_and_kerosene_sales/historical/ 2002/

foks_2002.html , accessed December 2009.

EIA, 2009c. Energy Information Administration, “20 06 Energy Consumption by Manufacturers

− Data Tables,” 2006

Manufacturing Energy Consumption Survey , U.S. Department of Energy, accessed from

http://www.eia.doe.gov/emeu/mecs/mecs2006/2006table s.html , issued June 2009.

EIA, 2009d. Energy Information Administration, “An nual Energy Outlook 2010 Early Release Overview,” D epartment

of Energy, accessed from http://www.eia.doe.gov/oiaf/aeo/index.html , released December 2009.

EPA, 2003a. U.S. Environmental Protection Agency, “Draft Regulatory Impact Analysis: Control of Emis sions from

Nonroad Diesel Engines,” EPA420-R-03-008, Office of Transportation and Air Quality, April 2003.

# January 2012

Final Report 

# 62 

# EPA, 2003b. U.S. Environmental Protection Agency, AP 42, Compilation of Air Pollutant Emission Factor s, Fifth

Edition , “Volume I, Chapter 1: External Combustion Sources , Section 1.6-Wood Residue in Combustion

Boilers,” accessed from http://www.epa.gov/ttn/chief/ap42/ch01/final/c01s06 .pdf , September 2003.

EPA, 2008a. U.S. Environmental Protection Agency, “Regulatory Impact Analysis: Control of Emissions of Air

Pollution from Locomotive Engines and Marine Compre ssion Ignition Engines Less than 30 Liters Per

Cylinder,” EPA420-R-08-001a, Assessment and Standar ds Division, Office of Transportation and Air Qualit y,

May 2008

EPA, 2008b. U.S. Environmental Protection Agency, “Regulatory Impact Analysis: Control of Emissions o f Air

Pollution from Category 3 Marine Diesel Engines, Ch apter 3 Emission Inventory,” EPA-420-R-09-019,

Assessment and Standards Division Office of Transpor tation and Air, December 2008.

EPA, 2009. U.S. Environmental Protection Agency, “ Economic Analysis of Final Effluent Limitation Guide lines and

Standards for the Construction and Development Indu stry,” Office of Water, October 21, 2009.

EPA, 2010. U.S. Environmental Protection Agency, E GAS Version 5.0, available for download from

http://www.epa.gov/ttnecas1/egas5.htm , accessed March 2010.

ERG, 2009a. Eastern Research Group, “Documentation for Aircraft Component of the National Emissions I nventory

Methodology,” prepared under subcontract to E.H. Pe chan and Associates, Inc. for U.S. Environmental

Protection Agency, Emissions, Monitoring and Analys is Division, December 15, 2009.

ERG, 2009b. Eastern Research Group, “Documentation for Commercial Marine Vessel Component of the Nati onal

Emissions Inventory Methodology,” prepared under su bcontract to E.H. Pechan and Associates, Inc. for U .S.

Environmental Protection Agency, Emissions, Monitor ing and Analysis Division, December 15, 2009.

ERTAC, 2010a. Eastern Regional Technical Advisory C ommittee, 2007 Class I line haul emissions, transmi tted in

file “EmissionsByCounty_Round6.xls” in email entitl ed “ERTAC update/Class I emissions,” from M. Bergin

, ERTAC to K. Thesing, E.H. Pechan & Associates, Inc., March 23, 2010.

ERTAC, 2010b. Eastern Regional Technical Advisory C ommittee, 2008 Class II/III line haul Emissions, tr ansmitted

in file “ClassII_III_v4.xls” in email entitled “Cla ss II/III Spreadsheet with Reporting Marks,” from M . Janssen,

LADCO to ERTAC distribution list, March 1, 2010.

ERTAC, 2010c. Eastern Regional Technical Advisory C ommittee, Railyard Emissions, transmitted in file “ ERTAC

Railyard switcher emissions inventory 6_4_2010.xls” in email from M. Bergin, ERTAC to ERTAC distributi on

list, June 4, 2010.

FAA, 2010. Federal Aviation Administration, “2007 a nd 2008 LTO operations by SESARM State,” obtained fr om Air

Traffic Activity System, http://aspm.faa.gov/opsnet/sys/Main.asp?force=atads , February 2010.

Huntley, 2009. Huntley, Roy, U.S. Environmental Pr otection Agency, “SCCs & emission factors to be use d in 2008

NEI to Bollman May 1 2009.mdb [ electronic file ],” May 1, 2009.

Lorenz, 2009. Lorenz, Thomas, Energy Information Ad ministration, personal communication with Jonathan Dorn,

E.H. Pechan & Associates, Inc., September 29, 2009.

Pechan, 2004. E.H. Pechan & Associates, Inc. “Esti mating Ammonia Emissions from Anthropogenic Nonagri cultural

Sources - Draft Final Report,” prepared for the Emis sion Inventory Improvement Program, April 2004.

# January 2012

Final Report 

# 63 

# Pechan, 2009a. E.H. Pechan and Associates, Inc., “ Non-Road and Area Source Base Year and Future Year

Emissions Inventories Technical Memorandum #1: Base Year Inventory – Summary of 2008 NEI Efforts,”

prepared for Southeastern States Air Resource Manag ers, Inc., September 14, 2009.

Pechan, 2009b. E.H. Pechan and Associates, Inc., “ Evaluation of ICI Combustion Coal Sulfur Content, T echnical

Memorandum,” prepared for Central Air Planning Asso ciation, March 28, 2009.

Pechan, 2009c. E.H. Pechan and Associates, Inc., “ Instructions To SESARM States For Updating EPA’s Nati onal

Mobile Inventory Model 2007 County-Level Database, Technical Memorandum,” prepared for SESARM,

September 18, 2009.

Pechan, 2010. E.H. Pechan and Associates, Inc., “A rea & Nonroad Base & Forecast Year Inventories, Fina l Report,”

prepared for Southeastern States Air Resource Manag ers, Inc., June 2010.

# January 2012



# A

- 1 Final Report 

# APPENDIX A. POINT SOURCE SUBTRACTION PROCEDURE DETAILS

This Appendix describes source category-specific det ails on the point source subtraction procedures, an d displays

the area SCC to point SCC crosswalk (see Tables A-1 through A-8).



# A. ICI FUEL COMBUSTION

To assist in the point source subtractions for indus trial, commercial, and institutional (ICI) fuel com bustion,

TranSystems developed two crosswalks: one between e ach industrial fuel combustion area SCC and associa ted

point SCCs (Table A-1), and an analogous crosswalk d eveloped for commercial/institutional fuel combusti on (Table

A-2).

Because natural gas consumed as pipeline fuel is no t included by the Energy Information Administration (EIA) in

EIA’s state energy consumption data for the Industr ial sector, it was necessary to exclude pipeline na tural gas

combustion emissions from the point source subtract ion procedure. Since there are no SCCs specific to pipeline

natural gas combustion, point source pipeline natur al gas combustion emission estimates were compiled by summing

emissions for industrial sector natural gas interna l combustion engine records (SCC 202002xx) with a p ipelinerelated Standard Industrial Classification (SIC) or North American Industrial Classification System (N AICS) code (SIC

codes 1311, 1321, 1381, 4612, 4613, 4619, 4922, 492 3, 4924, 4925, or 4931; NAICS codes 211111, 21112, 22121,

221210, 486110, 48621, 486210, 486910, 48699, or 48 6990).



# B. CONSTRUCTION DUST

Table A-3 displays the point SCCs associated with du st from Construction activities. These SCCs do not provide

information to separate activity into the two area source category processes:

• 2311010000 - Construction: SIC 15-17; Residential; Total; and

• 2311020000 - Construction: SIC 15-18; Industrial/Co mmercial/Institutional; Total.

TranSystems apportioned point source construction du st emissions between the two categories using state -level

acreage data reported in the EPA October 2008 repor t “Economic Analysis of Final Effluent Limitation Gu idelines and

Standards for the Construction and Development Indu stry” (EPA, 2009). These proportions for each SESAR M state

are displayed below.

# January 2012



# A

- 2 Final Report 

# Percentage of Construction Acreage by State and Type of Construction

State Residential % Other %

Alabama 36 64

Florida 41 59

Georgia 39 61

Kentucky 31 69

Mississippi 24 76

North Carolina 48 52

South Carolina 42 58

Tennessee 35 65

Virginia 45 55

West Virginia 40 60

Source: Table 4-8 from EPA, 2009.



# C. SOLVENT UTILIZATION

Table A-5 presents the point source crosswalk for ea ch solvent utilization nonpoint SCC. This crosswalk was derived

from the crosswalk used in performing VOC emissions -based point source subtractions for the 2002 NEI. As noted

in the Table A-5 crosswalk, two area source solvent utilization SCCs (2401005000-Auto Refinishing and

2401070000-Motor Vehicles) are associated with the same point SCCs. For the Auto Refinishing area sour ce

category, point source subtractions for the listed SCCs were limited to records identified with Auto R efinishing

industry sector SIC/NAICS codes (e.g., NAICS code 8 111*). Emissions for all other applicable point SC C S/L

inventory records were subtracted from total emissi ons for the Motor Vehicles source category.



# D. GASOLINE DISTRIBUTION

Table A-6 displays the point SCCs associated with ga soline distribution. Some of these SCCs do not pro vide

information to separate activity into each area sou rce stage I gasoline distribution filling technolog y. Therefore,

TranSystems allocated the emissions from these point SCCs to each filling technology based on the propo rtion of

emissions from TranSystems default inventory.January 2012Final ReportA-3Table A-1. Industrial Fuel Combustion Crosswalk for Point Source Subtractions.Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2102001000 - Stationary Source Fuel Combustion; Industrial; Anthracite Coal; Total: All Boiler Types10200101External CombustionBoilersIndustrialAnthracite CoalPulverized Coal10200104External Combustion BoilersIndustrialAnthracite CoalTraveling Grate (Overfeed) Stoker10200107External Combustion BoilersIndustrialAnthracite CoalHand-fired10200117ExternalCombustion BoilersIndustrialAnthracite CoalFluidized Bed Boiler Burning Anthracite-Culm Fuel39000189Industrial ProcessesIn-process Fuel UseAnthracite CoalGeneral39000199Industrial ProcessesIn-process Fuel UseAnthracite CoalGeneral2102002000 - Stationary Source Fuel Combustion; Industrial; Bituminous/Subbituminous Coal; Total: AllBoiler Types10200201External Combustion BoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Wet Bottom10200202External CombustionBoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Dry Bottom10200203External Combustion BoilersIndustrialBituminous/Subbituminous CoalCyclone Furnace10200204External Combustion BoilersIndustrialBituminous/Subbituminous CoalSpreader Stoker10200205External Combustion BoilersIndustrialBituminous/Subbituminous CoalOverfeed Stoker10200206External Combustion BoilersIndustrialBituminous/Subbituminous CoalUnderfeed Stoker10200210External Combustion BoilersIndustrialBituminous/Subbituminous CoalOverfeed Stoker **10200212External Combustion BoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Dry Bottom (Tangential)10200213External Combustion BoilersIndustrialBituminous/SubbituminousCoalWet Slurry10200217External Combustion BoilersIndustrialBituminous/Subbituminous CoalAtmospheric Fluidized Bed Combustion: BubblingBed (Bituminous Coal)10200218External Combustion BoilersIndustrialBituminous/Subbituminous CoalAtmosphericFluidized Bed Combustion: CirculatingBed (Bitum. Coal)10200219External Combustion BoilersIndustrialBituminous/Subbituminous CoalCogeneration (Bituminous Coal)10200221External Combustion BoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Wet Bottom (Subbituminous Coal)10200222External Combustion BoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Dry Bottom (Subbituminous Coal)10200223External Combustion BoilersIndustrialBituminous/SubbituminousCoalCyclone Furnace (Subbituminous Coal)10200224External Combustion BoilersIndustrialBituminous/Subbituminous CoalSpreader Stoker (Subbituminous Coal)10200225External Combustion BoilersIndustrialBituminous/Subbituminous CoalTraveling Grate(Overfeed) Stoker (SubbituminousCoal)10200226External Combustion BoilersIndustrialBituminous/Subbituminous CoalPulverized Coal: Dry Bottom Tangential(Subbituminous Coal)10200229External Combustion BoilersIndustrialBituminous/Subbituminous CoalCogeneration (Subbituminous Coal)10500102External Combustion BoilersSpace HeatersIndustrialCoal **39000201Industrial ProcessesIn-process Fuel UseBituminous CoalCement Kiln/Dryer (Bituminous Coal)39000203Industrial ProcessesIn-processFuel UseBituminous CoalLime Kiln (Bituminous)39000288Industrial ProcessesIn-process Fuel UseBituminous CoalGeneral (Subbituminous)January 2012Final ReportA-4Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments39000289Industrial ProcessesIn-process Fuel UseBituminous CoalGeneral (Bituminous)39000299IndustrialProcessesIn-process Fuel UseBituminous CoalGeneral (Bituminous)50390002Waste DisposalSolid Waste Disposal-IndustrialAuxiliary Fuel/No EmissionsCoal2102004000 - Stationary Source Fuel Combustion; Industrial; Distillate Oil; Total: Boilers and IC Engines10200501External Combustion BoilersIndustrialDistillate OilGrades 1 and 2 Oil10200502External Combustion BoilersIndustrialDistillate Oil10-100 Million Btu/hr **10200503External Combustion BoilersIndustrialDistillate Oil< 10Million Btu/hr **10200504External Combustion BoilersIndustrialDistillate OilGrade 4 Oil10200505External Combustion BoilersIndustrialDistillate OilCogeneration10201403External Combustion BoilersIndustrialCO BoilerDistillate Oil10500105External Combustion BoilersSpace HeatersIndustrialDistillate Oil20200101Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Turbine20200102Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Reciprocating20200103Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Turbine: Cogeneration20200104Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Reciprocating: Cogeneration20200105Internal Combustion EnginesIndustrialDistillateOil (Diesel)Reciprocating: Crankcase Blowby20200106Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Reciprocating: Evaporative Losses (Fuel Storageand Delivery System)20200107Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Reciprocating: Exhaust20200108Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Turbine: Evaporative Losses (Fuel Storage andDelivery System)20200109Internal Combustion EnginesIndustrialDistillate Oil (Diesel)Turbine:Exhaust20200401Internal Combustion EnginesIndustrialLarge Bore EngineDiesel20200405Internal Combustion EnginesIndustrialLarge Bore EngineCrankcase Blowby20200406Internal Combustion EnginesIndustrialLarge Bore EngineEvaporative Losses(Fuel Storage and DeliverySystem)20200407Internal Combustion EnginesIndustrialLarge Bore EngineExhaust27000320Internal Combustion EnginesOff-highway Diesel EnginesIndustrial EquipmentIndustrial Fork Lift: Diesel30190001IndustrialProcessesChemical ManufacturingFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30190011Industrial ProcessesChemical ManufacturingFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30190021Industrial ProcessesChemicalManufacturingFuel Fired EquipmentDistillate Oil (No. 2): Flares30290001Industrial ProcessesFood and AgricultureFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30390001Industrial ProcessesPrimary Metal ProductionFuel FiredEquipmentDistillate Oil (No. 2): Process Heaters30390011Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30390021Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentDistillateOil (No. 2): Flares30400406Industrial ProcessesSecondary Metal ProductionLeadPot Furnace Heater: Distillate OilJanuary 2012Final ReportA-5Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30490001Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30490011Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30490021Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentDistillate Oil (No. 2): Flares30490031Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentDistillate Oil (No. 2): Furnaces30500208Industrial ProcessesMineral ProductsAsphalt ConcreteAsphalt Heater: Distillate Oil30505022Industrial ProcessesMineral ProductsAsphalt Processing (Blowing)Asphalt Heater: Distillate Oil30590001Industrial ProcessesMineral ProductsFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30590011Industrial ProcessesMineral ProductsFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30590021Industrial ProcessesMineral ProductsFuel Fired EquipmentDistillate Oil (No. 2): Flares30600901Industrial ProcessesPetroleum IndustryFlaresDistillate Oil30609901Industrial ProcessesPetroleum IndustryIncineratorsDistillate Oil (No.2)30790001Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30790011Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30790021Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentDistillate Oil (No. 2): Flares30890001Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30890011Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentDistillate Oil (No. 2): Incinerators30890021Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentDistillate Oil (No. 2): Flares30990001Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentDistillate Oil (No. 2): Process Heaters30990011Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentDistillate Oil (No. 2): Incinerators31000401IndustrialProcessesOil and Gas ProductionProcess HeatersDistillate Oil (No. 2)31000411Industrial ProcessesOil and Gas ProductionProcess HeatersDistillate Oil (No. 2): Steam Generators31390001Industrial ProcessesElectrical EquipmentProcess HeatersDistillate Oil (No. 2)39000501Industrial ProcessesIn-process Fuel UseDistillate OilAsphalt Dryer **39000502Industrial ProcessesIn-process Fuel UseDistillate OilCement Kiln/Dryer39000503Industrial ProcessesIn-process Fuel UseDistillateOilLime Kiln39000589Industrial ProcessesIn-process Fuel UseDistillate OilGeneral39000598Industrial ProcessesIn-process Fuel UseDistillate OilGrade 4 Oil: General39000599Industrial ProcessesIn-process Fuel UseDistillate OilGeneral39900501Industrial ProcessesMiscellaneous ManufacturingIndustriesProcess Heater/FurnaceDistillate Oil39990001Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesDistillate Oil (No. 2): Process Heaters39990011Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesDistillate Oil (No. 2): IncineratorsJanuary 2012Final ReportA-6Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments39990021Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesDistillate Oil (No. 2 Oil): Flares40201002Petroleum and Solvent EvaporationSurface Coating OperationsCoating Oven HeaterDistillate Oil40290011Petroleum and Solvent EvaporationSurface Coating OperationsFuel Fired EquipmentDistillateOil: Incinerator/Afterburner49090011Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentDistillate Oil (No. 2): Incinerators49090021Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentDistillate Oil (No. 2): Flares50390005Waste DisposalSolid Waste Disposal-IndustrialAuxiliary Fuel/No EmissionsDistillate Oil2102005000 - Stationary Source Fuel Combustion; Industrial; Residual Oil; Total: All Boiler Types10200401ExternalCombustion BoilersIndustrialResidual OilGrade 6 Oil10200402External Combustion BoilersIndustrialResidual Oil10-100 Million Btu/hr **10200403External Combustion BoilersIndustrialResidual Oil< 10 Million Btu/hr **10200404ExternalCombustion BoilersIndustrialResidual OilGrade 5 Oil10200405External Combustion BoilersIndustrialResidual OilCogeneration10201404External Combustion BoilersIndustrialCO BoilerResidual Oil20200501Internal Combustion EnginesIndustrialResidual/Crude OilReciprocating20200505Internal Combustion EnginesIndustrialResidual/Crude OilReciprocating: Crankcase Blowby20200506Internal Combustion EnginesIndustrialResidual/Crude OilReciprocating: Evaporative Losses (Fuel Storageand Delivery System)20200507Internal Combustion EnginesIndustrialResidual/Crude OilReciprocating: Exhaust30190002Industrial ProcessesChemical ManufacturingFuel Fired EquipmentResidual Oil: Process Heaters30190012Industrial ProcessesChemicalManufacturingFuel Fired EquipmentResidual Oil: Incinerators30190022Industrial ProcessesChemical ManufacturingFuel Fired EquipmentResidual Oil: Flares30290002Industrial ProcessesFood and AgricultureFuel Fired EquipmentResidual Oil: ProcessHeaters30390002Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentResidual Oil: Process Heaters30390012Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentResidual Oil: Incinerators30390022Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentResidual Oil: Flares30490002Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentResidual Oil: Process Heaters30490012Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentResidual Oil: Incinerators30490022Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentResidual Oil: Flares30490032Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentResidual Oil: Furnaces30500207IndustrialProcessesMineral ProductsAsphalt ConcreteAsphalt Heater: Residual Oil30505021Industrial ProcessesMineral ProductsAsphalt Processing (Blowing)Asphalt Heater: Residual Oil30590002Industrial ProcessesMineral ProductsFuel Fired EquipmentResidual Oil: Process Heaters30590012Industrial ProcessesMineral ProductsFuel Fired EquipmentResidual Oil: Incinerators30600111Industrial ProcessesPetroleum IndustryProcess HeatersOil-fired (No. 6 Oil) > 100 Million Btu Capacity30600902Industrial ProcessesPetroleum IndustryFlaresResidual OilJanuary 2012Final ReportA-7Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30609902Industrial ProcessesPetroleum IndustryIncineratorsResidual Oil30790002Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentResidual Oil: Process Heaters30790012Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentResidual Oil: Incinerators30790022Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentResidual Oil: Flares30890002Industrial ProcessesRubberand MiscellaneousPlastics ProductsFuel Fired EquipmentResidual Oil: Process Heaters30890012Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentResidual Oil: Incinerators30890022Industrial ProcessesRubber andMiscellaneousPlastics ProductsFuel Fired EquipmentResidual Oil: Flares30990002Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentResidual Oil: Process Heaters30990012Industrial ProcessesFabricated Metal ProductsFuel FiredEquipmentResidual Oil: Incinerators31000402Industrial ProcessesOil and Gas ProductionProcess HeatersResidual Oil31000412Industrial ProcessesOil and Gas ProductionProcess HeatersResidual Oil: Steam Generators31390002Industrial ProcessesElectrical EquipmentProcess HeatersResidual Oil39000402Industrial ProcessesIn-process Fuel UseResidual OilCement Kiln/Dryer39000403Industrial ProcessesIn-process Fuel UseResidual OilLime Kiln39000489Industrial ProcessesIn-process FuelUseResidual OilGeneral39000499Industrial ProcessesIn-process Fuel UseResidual OilGeneral39990002Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesResidual Oil: Process Heaters39990012Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesResidual Oil: Incinerators39990022Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesResidual Oil: Flares40201003Petroleum and Solvent EvaporationSurface Coating OperationsCoating Oven HeaterResidual Oil40290012Petroleum and Solvent EvaporationSurface Coating OperationsFuel Fired EquipmentResidual Oil: Incinerator/Afterburner49090012Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentResidual Oil: Incinerators49090022Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentResidual Oil: Flares2102006000 - Stationary Source Fuel Combustion; Industrial; Natural Gas; Total: Boilers and IC Engines10200601External Combustion BoilersIndustrialNatural Gas> 100 Million Btu/hr10200602External Combustion BoilersIndustrialNatural Gas10-100 Million Btu/hr10200603External Combustion BoilersIndustrialNatural Gas< 10 Million Btu/hr10200604External Combustion BoilersIndustrialNatural GasCogeneration10201401External Combustion BoilersIndustrialCO BoilerNatural Gas10500106External Combustion BoilersSpace HeatersIndustrialNatural GasJanuary 2012Final ReportA-8Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments20200201Internal Combustion EnginesIndustrialNatural GasTurbineExclude compressorstation natural gas20200202Internal Combustion EnginesIndustrialNatural GasReciprocatingExclude compressorstation natural gas20200203Internal Combustion EnginesIndustrialNatural GasTurbine: CogenerationExclude compressorstation natural gas20200204Internal Combustion EnginesIndustrialNatural GasReciprocating: CogenerationExclude compressorstation natural gas20200205Internal Combustion EnginesIndustrialNatural GasReciprocating: Crankcase BlowbyExclude compressorstation natural gas20200206Internal Combustion EnginesIndustrialNatural GasReciprocating: Evaporative Losses (Fuel DeliverySystem)Excludecompressorstation natural gas20200207Internal Combustion EnginesIndustrialNatural GasReciprocating: ExhaustExclude compressorstation natural gas20200208Internal Combustion EnginesIndustrialNatural GasTurbine: Evaporative Losses (FuelDeliverySystem)Exclude compressorstation natural gas20200209Internal Combustion EnginesIndustrialNatural GasTurbine: ExhaustExclude compressorstation natural gas20200251Internal Combustion EnginesIndustrialNatural Gas2-cycle Rich BurnExclude compressorstation natural gas20200252Internal Combustion EnginesIndustrialNatural Gas2-cycle Lean BurnExclude compressorstation natural gas20200253Internal Combustion EnginesIndustrialNatural Gas4-cycle Rich BurnExclude compressorstation natural gas20200254Internal Combustion EnginesIndustrialNatural Gas4-cycle Lean BurnExclude compressorstation natural gas20200255Internal Combustion EnginesIndustrialNatural Gas2-cycle Clean BurnExclude compressorstation natural gas20200256Internal Combustion EnginesIndustrialNatural Gas4-cycle Clean BurnExclude compressorstation natural gas30190003Industrial ProcessesChemical ManufacturingFuel Fired EquipmentNatural Gas: Process Heaters30190013Industrial ProcessesChemical ManufacturingFuel Fired EquipmentNatural Gas: Incinerators30190023Industrial ProcessesChemical ManufacturingFuel Fired EquipmentNatural Gas: Flares30290003Industrial ProcessesFood and AgricultureFuel Fired EquipmentNatural Gas:Process Heaters30291001Industrial ProcessesFood and AgricultureFuel Fired EquipmentBroiling Food: Natural Gas30390003Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentNatural Gas: Process Heaters30390013Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentNatural Gas: Incinerators30390023Industrial ProcessesPrimary Metal ProductionFuel Fired EquipmentNatural Gas: Flares30400407Industrial ProcessesSecondary Metal ProductionLeadPot Furnace Heater:Natural Gas30490003Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentNatural Gas: Process Heaters30490013Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentNatural Gas: Incinerators30490023IndustrialProcessesSecondary Metal ProductionFuel Fired EquipmentNatural Gas: Flares30490033Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentNatural Gas: FurnacesJanuary 2012Final ReportA-9Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30500206Industrial ProcessesMineral ProductsAsphalt ConcreteAsphaltHeater: Natural Gas30505020Industrial ProcessesMineral ProductsAsphalt Processing (Blowing)Asphalt Heater: Natural Gas30590003Industrial ProcessesMineral ProductsFuel Fired EquipmentNatural Gas: Process Heaters30590013Industrial ProcessesMineral ProductsFuel Fired EquipmentNatural Gas: Incinerators30590023Industrial ProcessesMineral ProductsFuel Fired EquipmentNatural Gas: Flares30600105Industrial ProcessesPetroleum IndustryProcess HeatersNatural Gas30600903IndustrialProcessesPetroleum IndustryFlaresNatural Gas30602401Industrial ProcessesPetroleum IndustryReciprocating Engine CompressorsNatural Gas Fired30609903Industrial ProcessesPetroleum IndustryIncineratorsNatural Gas30790003IndustrialProcessesPulp and Paper and WoodProductsFuel Fired EquipmentNatural Gas: Process Heaters30790013Industrial ProcessesPulp and Paper and WoodProductsFuel Fired EquipmentNatural Gas: Incinerators30790023Industrial ProcessesPulp and Paper andWoodProductsFuel Fired EquipmentNatural Gas: Flares30890003Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentNatural Gas: Process Heaters30890013Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentNatural Gas: Incinerators30890023Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentNatural Gas: Flares30990003Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentNatural Gas:Process Heaters30990013Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentNatural Gas: Incinerators30990023Industrial ProcessesFabricated Metal ProductsFuel Fired EquipmentNatural Gas: Flares31000404Industrial ProcessesOiland Gas ProductionProcess HeatersNatural Gas31000414Industrial ProcessesOil and Gas ProductionProcess HeatersNatural Gas: Steam Generators31390003Industrial ProcessesElectrical EquipmentProcess HeatersNatural Gas39000602IndustrialProcessesIn-process Fuel UseNatural GasCement Kiln/Dryer39000603Industrial ProcessesIn-process Fuel UseNatural GasLime Kiln39000605Industrial ProcessesIn-process Fuel UseNatural GasMetal Melting **39000689Industrial ProcessesIn-process Fuel UseNatural GasGeneral39000699Industrial ProcessesIn-process Fuel UseNatural GasGeneral39900601Industrial ProcessesMiscellaneous ManufacturingIndustriesProcess Heater/FurnaceNatural Gas39990003Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesNatural Gas: Process Heaters39990013Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesNatural Gas: Incinerators39990023Industrial ProcessesMiscellaneous ManufacturingIndustriesMiscellaneous ManufacturingIndustriesNatural Gas: FlaresJanuary 2012Final ReportA-10Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40201001Petroleum and Solvent EvaporationSurface Coating OperationsCoating Oven HeaterNatural Gas40290013Petroleum and SolventEvaporationSurface Coating OperationsFuel Fired EquipmentNatural Gas: Incinerator/Afterburner40290023Petroleum and Solvent EvaporationSurface Coating OperationsFuel Fired EquipmentNatural Gas: Flares49090013Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentNatural Gas: Incinerators49090023Petroleum and Solvent EvaporationOrganic Solvent EvaporationFuel Fired EquipmentNatural Gas: Flares50390006Waste DisposalSolid Waste Disposal-IndustrialAuxiliary Fuel/No EmissionsNatural Gas2102007000 - Stationary Source Fuel Combustion; Industrial; Liquified Petroleum Gas (LPG); Total: AllBoiler Types10201001External Combustion BoilersIndustrialLiquified Petroleum Gas (LPG)Butane10201002External Combustion BoilersIndustrialLiquified Petroleum Gas (LPG)Propane10201003External Combustion BoilersIndustrialLiquified Petroleum Gas (LPG)Butane/Propane Mixture: Specify Percent Butane inComments10500110External Combustion BoilersSpace HeatersIndustrialLiquified Petroleum Gas (LPG)20201001Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Propane: Reciprocating20201002Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Butane:Reciprocating20201005Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Reciprocating: Crankcase Blowby20201006Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Reciprocating: Evaporative Losses (Fuel Storageand Delivery System)20201007Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Reciprocating: Exhaust20201008Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Turbine: Evaporative Losses (Fuel Storage andDelivery System)20201009Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Turbine: Exhaust20201011Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Turbine20201012Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Reciprocating Engine20201013Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Turbine: Cogeneration20201014Internal Combustion EnginesIndustrialLiquified Petroleum Gas (LPG)Reciprocating Engine: Cogeneration27300320Internal Combustion EnginesOff-highway LPG-fueled EnginesIndustrial EquipmentIndustrial Fork Lift: Liquified Petroleum Gas (LPG)30290005Industrial ProcessesFood and AgricultureFuel Fired EquipmentLiquified Petroleum Gas(LPG): Process Heaters30490035Industrial ProcessesSecondary Metal ProductionFuel Fired EquipmentPropane: Furnaces30500209Industrial ProcessesMineral ProductsAsphalt ConcreteAsphalt Heater: LPG30505023Industrial ProcessesMineral ProductsAsphalt Processing (Blowing)Asphalt Heater: LP Gas30590005Industrial ProcessesMineral ProductsFuel Fired EquipmentLiquified Petroleum Gas (LPG): Process Heaters30600107Industrial ProcessesPetroleum IndustryProcess HeatersLPG-fired30600905Industrial ProcessesPetroleum IndustryFlaresLiquified Petroleum Gas30609905Industrial ProcessesPetroleum IndustryIncineratorsLiquified Petroleum Gas30890004Industrial ProcessesRubber and MiscellaneousPlastics ProductsFuel Fired EquipmentLiquified Petroleum Gas (LPG): Process Heaters31000406Industrial ProcessesOil and Gas ProductionProcess HeatersPropane/ButaneJanuary 2012Final ReportA-11Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments39001089Industrial ProcessesIn-process Fuel UseLiquified Petroleum GasGeneral39001099Industrial ProcessesIn-process Fuel UseLiquified Petroleum GasGeneral39901001Industrial ProcessesMiscellaneous ManufacturingIndustriesProcess Heater/FurnaceLPG40201004Petroleum and Solvent EvaporationSurface Coating OperationsCoating Oven HeaterLiquifiedPetroleum Gas (LPG)50390010Waste DisposalSolid Waste Disposal-IndustrialAuxiliary Fuel/No EmissionsLiquified Petroleum Gas (LPG)2102008000 - Stationary Source Fuel Combustion; Industrial; Wood; Total: All Boiler Types10200901ExternalCombustion BoilersIndustrialWood/Bark WasteBark-fired Boiler10200902External Combustion BoilersIndustrialWood/Bark WasteWood/Bark-fired Boiler10200903External Combustion BoilersIndustrialWood/Bark WasteWood-fired Boiler-Wet Wood (>=20%moisture)10200904External Combustion BoilersIndustrialWood/Bark WasteBark-fired Boiler (< 50,000 Lb Steam) **10200905External Combustion BoilersIndustrialWood/Bark WasteWood/Bark-fired Boiler (< 50,000 Lb Steam) **10200906ExternalCombustion BoilersIndustrialWood/Bark WasteWood-fired Boiler (< 50,000 Lb Steam) **10200907External Combustion BoilersIndustrialWood/Bark WasteWood Cogeneration10200908External Combustion BoilersIndustrialWood/Bark WasteWood-fired Boiler-Dry Wood (<20% moisture)10200910External Combustion BoilersIndustrialWood/Bark WasteFuel cell/Dutch oven boilers **10200911External Combustion BoilersIndustrialWood/Bark WasteStoker boilers **10200912External Combustion BoilersIndustrialWood/Bark WasteFluidized bed combustion boiler39000989Industrial ProcessesIn-process Fuel UseWoodGeneral39000999Industrial ProcessesIn-process Fuel UseWoodGeneral: Wood2102011000 - Stationary Source Fuel Combustion; Industrial; Kerosene; Total: All Boiler Types20200901Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Turbine20200902Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Reciprocating20200905Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Reciprocating: Crankcase Blowby20200906Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Reciprocating: Evaporative Losses (Fuel Storageand Delivery System)20200907Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Reciprocating: Exhaust20200908Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Turbine: Evaporative Losses (Fuel Storage andDelivery System)20200909Internal Combustion EnginesIndustrialKerosene/Naphtha (Jet Fuel)Turbine: ExhaustJanuary 2012Final ReportA-12Table A-2. Commercial/Institutional Fuel Combustion Crosswalk for Point Source SubtractionsPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2103001000 - Stationary Source Fuel Combustion; Commercial/Institutional; Anthracite Coal; Total: AllBoiler Types10300101External Combustion BoilersCommercial/InstitutionalAnthracite CoalPulverized Coal10300102External Combustion BoilersCommercial/InstitutionalAnthracite CoalTravelingGrate (Overfeed) Stoker10300103External Combustion BoilersCommercial/InstitutionalAnthracite CoalHand-fired2103002000 - Stationary Source Fuel Combustion; Commercial/Institutional; Bituminous/Subbituminous Coal; Total: All Boiler Types10300203External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalCyclone Furnace (Bituminous Coal)10300205External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Wet Bottom (Bituminous Coal)10300206External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Dry Bottom (Bituminous Coal)10300207External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalOverfeed Stoker (Bituminous Coal)10300208External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalUnderfeed Stoker (Bituminous Coal)10300209External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalSpreader Stoker(Bituminous Coal)10300211External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalOverfeed Stoker **10300214External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalHand-fired (Bituminous Coal)10300216External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Dry Bottom (Tangential) (Bituminous Coal)10300217External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalAtmosphericFluidized Bed Combustion: Bubbling Bed (BituminousCoal)10300218External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalAtmospheric Fluidized Bed Combustion: Circulating Bed (Bitum.Coal)10300221External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Wet Bottom (Subbituminous Coal)10300222External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Dry Bottom (Subbituminous Coal)10300223External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalCyclone Furnace (Subbituminous Coal)10300224External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalSpreader Stoker (SubbituminousCoal)10300225External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalTraveling Grate (Overfeed) Stoker (Subbituminous Coal)10300226External Combustion BoilersCommercial/InstitutionalBituminous/Subbituminous CoalPulverized Coal: Dry Bottom Tangential (Subbituminous Coal)10500202External Combustion BoilersSpace HeatersCommercial/InstitutionalCoal **50190002Waste DisposalSolid Waste Disposal-GovernmentAuxiliary Fuel/No EmissionsCoal50290002WasteDisposalSolid Waste Disposal-Commercial/InstitutionalAuxiliary Fuel/No EmissionsCoal2103004000 - Stationary Source Fuel Combustion; Commercial/Institutional; Distillate Oil; Total: Boilers and IC Engines10300501External Combustion BoilersCommercial/InstitutionalDistillate OilGrades 1 and 2 Oil10300502External Combustion BoilersCommercial/InstitutionalDistillate Oil10-100 Million Btu/hr **10300503External Combustion BoilersCommercial/InstitutionalDistillate Oil< 10 MillionBtu/hr **10300504External Combustion BoilersCommercial/InstitutionalDistillate OilGrade 4 OilJanuary 2012Final ReportA-13Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments10500205External Combustion BoilersSpace HeatersCommercial/InstitutionalDistillate Oil20300101Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Reciprocating20300102Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Turbine20300105Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Reciprocating: Crankcase Blowby20300106Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Reciprocating: Evaporative Losses (Fuel Storage andDeliverySystem)20300107Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Reciprocating: Exhaust20300108Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Turbine: Evaporative Losses (Fuel Storage and Delivery System)20300109Internal Combustion EnginesCommercial/InstitutionalDistillate Oil (Diesel)Turbine: Exhaust50100602Waste DisposalSolid Waste Disposal-GovernmentFire FightingStructure: Distillate Oil50190005Waste DisposalSolid Waste Disposal-GovernmentAuxiliary Fuel/No EmissionsDistillate Oil50290005Waste DisposalSolid Waste Disposal-Commercial/InstitutionalAuxiliary Fuel/No EmissionsDistillate Oil2103005000 - Stationary Source Fuel Combustion; Commercial/Institutional; Residual Oil; Total: All Boiler Types10300401External Combustion BoilersCommercial/InstitutionalResidual OilGrade 6 Oil10300402External Combustion BoilersCommercial/InstitutionalResidual Oil10-100 Million Btu/hr **10300403External Combustion BoilersCommercial/InstitutionalResidual Oil< 10 Million Btu/hr **10300404External Combustion BoilersCommercial/InstitutionalResidual OilGrade 5 Oil2103006000 - Stationary Source Fuel Combustion; Commercial/Institutional; Natural Gas; Total: Boilersand IC Engines10300601ExternalCombustion BoilersCommercial/InstitutionalNatural Gas> 100 Million Btu/hr10300602External Combustion BoilersCommercial/InstitutionalNatural Gas10-100 Million Btu/hr10300603External Combustion BoilersCommercial/InstitutionalNatural Gas< 10Million Btu/hr10500206External Combustion BoilersSpace HeatersCommercial/InstitutionalNatural Gas20300201Internal Combustion EnginesCommercial/InstitutionalNatural GasReciprocating20300202Internal Combustion EnginesCommercial/InstitutionalNatural GasTurbine20300203Internal Combustion EnginesCommercial/InstitutionalNatural GasTurbine: Cogeneration20300204Internal Combustion EnginesCommercial/InstitutionalNatural GasCogeneration20300205InternalCombustion EnginesCommercial/InstitutionalNatural GasReciprocating: Crankcase Blowby20300206Internal Combustion EnginesCommercial/InstitutionalNatural GasReciprocating: Evaporative Losses (Fuel Delivery System)20300207Internal CombustionEnginesCommercial/InstitutionalNatural GasReciprocating: Exhaust20300208Internal Combustion EnginesCommercial/InstitutionalNatural GasTurbine: Evaporative Losses (Fuel Delivery System)20300209Internal Combustion EnginesCommercial/InstitutionalNatural GasTurbine: Exhaust50190006Waste DisposalSolid Waste Disposal-GovernmentAuxiliary Fuel/No EmissionsNatural GasJanuary 2012Final ReportA-14Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments50290006Waste DisposalSolid Waste Disposal-Commercial/InstitutionalAuxiliary Fuel/No EmissionsNatural Gas2103007000 - Stationary Source Fuel Combustion; Commercial/Institutional; Liquified Petroleum Gas (LPG); Total: All Combustor Types10301001External Combustion BoilersCommercial/InstitutionalLiquified Petroleum Gas (LPG)Butane10301002ExternalCombustion BoilersCommercial/InstitutionalLiquified Petroleum Gas (LPG)Propane10301003External Combustion BoilersCommercial/InstitutionalLiquified Petroleum Gas (LPG)Butane/Propane Mixture: Specify Percent Butane in Comments10500210ExternalCombustion BoilersSpace HeatersCommercial/InstitutionalLiquified Petroleum Gas (LPG)20301001Internal Combustion EnginesCommercial/InstitutionalLiquified Petroleum Gas (LPG)Propane: Reciprocating20301002Internal Combustion EnginesCommercial/InstitutionalLiquified Petroleum Gas (LPG)Butane: Reciprocating20301005Internal Combustion EnginesCommercial/InstitutionalLiquified Petroleum Gas (LPG)Reciprocating: Crankcase Blowby20301006Internal Combustion EnginesCommercial/InstitutionalLiquified Petroleum Gas (LPG)Reciprocating: Evaporative Losses (Fuel Storage andDeliverySystem)20301007Internal Combustion EnginesCommercial/InstitutionalLiquified Petroleum Gas (LPG)Reciprocating: Exhaust50190010Waste DisposalSolid Waste Disposal-GovernmentAuxiliary Fuel/No EmissionsLiquified Petroleum Gas (LPG)50290010Waste DisposalSolid Waste Disposal-Commercial/InstitutionalAuxiliary Fuel/No EmissionsLiquified Petroleum Gas (LPG)2103008000 - Stationary Source Fuel Combustion; Commercial/Institutional; Wood; Total: All Boiler Types10300901External Combustion BoilersCommercial/InstitutionalWood/Bark WasteBark-fired Boiler10300902External Combustion BoilersCommercial/InstitutionalWood/Bark WasteWood/Bark-fired Boiler10300903External Combustion BoilersCommercial/InstitutionalWood/Bark WasteWood-fired Boiler-Wet Wood (>=20% moisture)10300908External Combustion BoilersCommercial/InstitutionalWood/Bark WasteWood-firedBoiler-Dry Wood (<20% moisture)10300910External Combustion BoilersCommercial/InstitutionalWood/Bark WasteFuel cell/Dutch oven boilers **10300911External Combustion BoilersCommercial/InstitutionalWood/Bark WasteStoker boilers **10300912External Combustion BoilersCommercial/InstitutionalWood/Bark WasteFluidized bed combustion boilers10500209External Combustion BoilersSpace HeatersCommercial/InstitutionalWood2103011000 - Stationary Source Fuel Combustion; Commercial/Institutional; Kerosene; Total: All Combustor Types20300901Internal Combustion EnginesCommercial/InstitutionalKerosene/Naphtha (Jet Fuel)Turbine: JP-420300908Internal Combustion EnginesCommercial/InstitutionalKerosene/Naphtha (JetFuel)Turbine: Evaporative Losses (Fuel Storage and Delivery System)20300909Internal Combustion EnginesCommercial/InstitutionalKerosene/Naphtha (Jet Fuel)Turbine: Exhaust50100603Waste DisposalSolid Waste Disposal-GovernmentFire FightingStructure: KeroseneJanuary 2012Final ReportA-15Table A-3. Construction Crosswalk for Point SourceSubtractionsPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2311010000-Industrial Processes; Construction: SIC 15–17; Residential; Totaland2311020000 - Industrial Processes; Construction: SIC 15 – 18; Industrial/Commercial/Institutional; Total31100101Industrial ProcessesBuilding ConstructionConstruction: Building ContractorsSite Preparation: Topsoil RemovalSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100102Industrial ProcessesBuilding ConstructionConstruction: Building ContractorsSite Preparation: Earth Moving (Cut and Fill)See Table II-2 for state-level SCC231101000 versus 2310020000proportions31100103Industrial ProcessesBuilding ConstructionConstruction: Building ContractorsSite Preparation: Aggregate Hauling (On Dirt)See Table II-2 for state-level SCC231101000 versus 2310020000proportions31100199Industrial ProcessesBuildingConstructionConstruction: Building ContractorsOther Not ClassifiedSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100201Industrial ProcessesBuilding ConstructionDemolitions/Special TradeContractsMechanical or ExplosiveDismembermentSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100202Industrial ProcessesBuilding ConstructionDemolitions/Special TradeContractsMechanical or Explosive DismembermentSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100205Industrial ProcessesBuilding ConstructionDemolitions/Special TradeContractsOn-site Truck TrafficSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100206Industrial ProcessesBuilding ConstructionDemolitions/Special TradeContractsOn-site Truck TrafficSee Table II-2 for state-level SCC231101000 versus 2310020000proportions31100299Industrial ProcessesBuilding ConstructionDemolitions/Special TradeContractsOther Not Classified: Construction/DemolitionSee Table II-2 for state-level SCC231101000 versus 2310020000proportionsJanuary 2012Final ReportA-16Table A-4. Publicly Owned Treatment Works Crosswalk for Point Source SubtractionsPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2630020000 - Waste Disposal, Treatment, and Recovery; Wastewater Treatment; Public Owned; Total Processed50100701Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentEntire Plant50100702Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPrimary Settling Tank50100703Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentSecondary Settling Tank50100704Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentAeration Tank50100707Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Headworks Screening50100708Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentComminutor50100710Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentCollectorSewers50100715Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Aerated Grit Chamber50100719Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentLift Station50100720Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Primary Settling Tank50100731Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Diffused Air Act Sludge50100732Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: MechanicalMix Air Act Sludge50100733Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Pure Oxygen Act Sludge50100734Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Trickling Filter50100740Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Secondary Clarifier50100750Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Tertiary Filters50100760Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Chlorine Contact Tank50100761Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Dechlorination50100765Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentWeir50100769Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentStorage Basin or Open Tank50100771Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Gravity Sludge Thickener50100772Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: DAFSludge Thickener50100781Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Anaerobic Digester50100791Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Belt Filter Press50100792Waste DisposalSolidWaste Disposal-GovernmentSewage TreatmentPOTW: Sludge Centrifuge50100793Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentPOTW: Sludge Drying Bed50100795Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentSludgeStorage Lagoons/Drying Beds50100799Waste DisposalSolid Waste Disposal-GovernmentSewage TreatmentOther Not ClassifiedJanuary 2012Final ReportA-17Table A-5. Solvent Utilization Crosswalk for PointSource SubtractionsPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2401005000 - Solvent Utilization; Surface Coating;Auto Refinishing: SIC 7532; Total: All Solvent Types40201601Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrimeApplication/Electo-deposition/Dip/SprayOnly include if NAICS code= 8111*40201602Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksCleaning/PretreatmentOnly include if NAICS code= 8111*40201603Petroleum andSolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksCoating MixingOnly include if NAICS code= 8111*40201604Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksCoating StorageOnly include if NAICS code= 8111*40201605Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksEquipment CleanupOnly include if NAICS code= 8111*40201606Petroleum and SolventEvaporationSurface Coating OperationsAutomobilesand Light TrucksTopcoat OperationOnly include if NAICS code= 8111*40201607Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksSealersOnly include if NAICS code= 8111*40201608Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksDeadenersOnly include if NAICS code= 8111*40201609Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksAnti-corrosion PrimingOnly include if NAICS code= 8111*40201619Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Surfacing OperationOnly include if NAICS code= 8111*40201620Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksRepair Topcoat Application AreaOnly include if NAICS code= 8111*40201621Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Solvent-borne-AutomobilesOnly include if NAICS code= 8111*40201622Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Electro-deposition-AutomobilesOnly include if NAICS code= 8111*40201623Petroleum and SolventEvaporationSurfaceCoating OperationsAutomobiles and Light TrucksGuide Coating: Solvent-borne-AutomobilesOnly include if NAICS code= 8111*40201624Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksGuide Coating: Water-borne-AutomobilesOnly include if NAICS code= 8111*40201625Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Solvent-borne-AutomobilesOnly include if NAICS code= 8111*40201626Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Water-borne-AutomobilesOnly include if NAICS code= 8111*40201627Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Solvent-borne-Light TrucksOnly include if NAICS code= 8111*40201628Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Electro-deposition-Light TrucksOnly include if NAICS code= 8111*40201629Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksGuide Coating: Solvent-borne-Light TrucksOnly include if NAICS code= 8111*40201630Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles andLight TrucksGuide Coating: Water-borne-Light TrucksOnly include if NAICS code= 8111*40201631Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Solvent-borne-Light TrucksOnly include if NAICS code= 8111*January 2012Final ReportA-18Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40201632Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Water-borne-Light TrucksOnly include if NAICS code= 8111*40201699Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksOther Not ClassifiedOnly include if NAICS code= 8111*2401015000 - Solvent Utilization; Surface Coating;Factory Finished Wood: SIC 2426 thru 242; Total: All Solvent Types40202101Petroleum and SolventEvaporationSurfaceCoating OperationsFlatwood ProductsBase Coat40202103Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsCoating Mixing40202104Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsCoatingStorage40202105Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsEquipment Cleanup40202106Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsTopcoat40202107Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsFiller40202108Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsSealer40202109Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsInks40202110Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsGrove Coat Application40202111Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsStain Application40202117Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsFiller Sander40202118Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsSealer Sander40202131Petroleum and SolventEvaporationSurface Coating OperationsFlatwoodProductsWater-borne Coating40202132Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsSolvent-borne Coating40202133Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsUltraviolet Coating40202140Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsSurface Preparation (Includes Tempering, Sanding,Brushing, Grove Cut)40202199Petroleum and SolventEvaporationSurface Coating OperationsFlatwood ProductsOtherNot Classified2401020000 - Solvent Utilization; Surface Coating;Wood Furniture: SIC 25; Total: All Solvent Types40201901Petroleum and SolventEvaporationSurface Coating OperationsWood Furniture Surface CoatingCoating Operation40201903Petroleum and SolventEvaporationSurface Coating OperationsWood Furniture Surface CoatingCoating Mixing40201904Petroleum and SolventEvaporationSurface Coating OperationsWood Furniture Surface CoatingCoating StorageJanuary 2012Final ReportA-19Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40201999Petroleum andSolventEvaporationSurface Coating OperationsWood Furniture Surface CoatingOther Not Classified2401025000 - Solvent Utilization; Surface Coating;Metal Furniture: SIC 25; Total: All Solvent Types40202001Petroleum and SolventEvaporationSurfaceCoating OperationsMetal Furniture OperationsCoating Operation40202002Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsCleaning/Pretreatment40202003Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsCoating Mixing40202004Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsCoating Storage40202005Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsEquipment Cleanup40202010Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsPrime Coat Application40202011Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsPrime CoatApplication: Spray, High Solids40202012Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsPrime Coat Application: Spray, Water-borne40202013Petroleum and SolventEvaporationSurface Coating OperationsMetalFurniture OperationsPrime Coat Application: Dip40202014Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsPrime Coat Application: Flow Coat40202015Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsPrime Coat Application: Flashoff40202020Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsTopcoat Application40202021Petroleum and SolventEvaporationSurface Coating OperationsMetalFurniture OperationsTopcoat Application: Spray, High Solids40202022Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsTopcoat Application: Spray, Water-borne40202023Petroleum and SolventEvaporationSurfaceCoating OperationsMetal Furniture OperationsTopcoat Application: Dip40202024Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsTopcoat Application: Flow Coat40202025Petroleum and SolventEvaporationSurfaceCoating OperationsMetal Furniture OperationsTopcoat Application: Flashoff40202031Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle Spray Line: General40202032Petroleum and SolventEvaporationSurfaceCoating OperationsMetal Furniture OperationsSpray Dip Line: General ** (Use 4-02-020-37)40202033Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSpray High Solids Coating ** (Use 4-02-020-35)40202034Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSpray Water-borne Coating ** (Use 4-02-020-36)40202035Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle CoatApplication: Spray, High SolidsJanuary 2012Final ReportA-20Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40202036Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle Coat Application: Spray, Water-borne40202037Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle Coat Application: Dip40202038Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle Coat Application: Flow Coat40202039Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsSingle Coat Application: Flashoff40202099Petroleum and SolventEvaporationSurface Coating OperationsMetal Furniture OperationsOther Not Classified2401030000 - Solvent Utilization; Surface Coating;Paper: SIC 26; Total: All Solvent Types40201301Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingCoating Operation40201303Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingCoating Mixing40201304Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingCoating Storage40201305Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingEquipment Cleanup40201310Petroleum and SolventEvaporationSurface Coating OperationsPaperCoatingCoating Application: Knife Coater40201320Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingCoating Application: Reverse Roll Coater40201330Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingCoating Application: Rotogravure Printer40201399Petroleum and SolventEvaporationSurface Coating OperationsPaper CoatingOther Not Classified2401040000 - Solvent Utilization; Surface Coating;Metal Cans: SIC 341; Total: All Solvent Types40201702Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingCleaning/Pretreatment40201703Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingCoating Mixing40201704Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingCoating Storage40201705Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingEquipment Cleanup40201706Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingSolvent Storage40201721Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingTwo Piece Exterior Base Coating40201722Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingInterior Spray Coating40201723Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingSheet Base Coating (Interior)40201724Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingSheet Base Coating (Exterior)January 2012Final ReportA-21Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40201725Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingSide Seam Spray Coating40201726Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingEnd Sealing Compound (Also See 4-02-017-36 &-37)40201727Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingLithography40201728Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingOver Varnish40201729Petroleum and SolventEvaporationSurface CoatingOperationsMetal Can CoatingExterior End Coating40201731Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingThree-piece Can Sheet Base Coating40201732Petroleum and SolventEvaporationSurface Coating OperationsMetal CanCoatingThree-piece Can Sheet Lithographic Coating Line40201733Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingThree-piece Can-side Seam Spray Coating40201734Petroleum and SolventEvaporationSurface CoatingOperationsMetal Can CoatingThree-piece Can Interior Body Spray Coat40201735Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingTwo-piece Can Coating Line40201736Petroleum and SolventEvaporationSurface CoatingOperationsMetal Can CoatingTwo-piece Can End Sealing Compound40201737Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingThree Piece Can End Sealing Compound40201738Petroleum and SolventEvaporationSurface CoatingOperationsMetal Can CoatingTwo Piece Can Lithographic Coating Line40201739Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingThree Piece Can Coating Line (All Coating SolventEmission Points)40201799Petroleum and SolventEvaporationSurface Coating OperationsMetal Can CoatingOther Not Classified2401045000 - Solvent Utilization; Surface Coating;Metal Coils: SIC 3498; Total: All Solvent Types40201801Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingPrime Coating Application40201802Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingCleaning/Pretreatment40201803Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingSolventMixing40201804Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingSolvent Storage (Use 4-07-004-01 thru 4-07-999-98 ifpossible)40201805Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingEquipment Cleanup40201806Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingFinish Coating40201807Petroleum and SolventEvaporationSurface Coating OperationsMetal Coil CoatingCoating Storage40201899Petroleum andSolventEvaporationSurface Coating OperationsMetal Coil CoatingOther Not ClassifiedJanuary 2012Final ReportA-22Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2401055000 - Solvent Utilization; Surface Coating;Machinery and Equipment: SIC 35; Total: All SolventTypes40202501Petroleum and SolventEvaporationSurfaceCoating OperationsMiscellaneous Metal PartsCoating Operation40202502Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsCleaning/Pretreatment40202503Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsCoating Mixing40202504Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsCoating Storage40202505Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsEquipment Cleanup40202510Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsPrime Coat Application40202511Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsPrime CoatApplication: Spray, High Solids40202512Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsPrime Coat Application: Spray, Water-borne40202515Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsPrime Coat Application: Flashoff40202520Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsTopcoat Application40202521Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsTopcoat Application: Spray, High Solids40202522Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsTopcoat Application: Spray, Water-borne40202523Petroleum and SolventEvaporationSurfaceCoating OperationsMiscellaneous Metal PartsTopcoat Application: Dip40202524Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsTopcoat Application: Flow Coat40202525Petroleum and SolventEvaporationSurfaceCoating OperationsMiscellaneous Metal PartsTopcoat Application: Flashoff40202531Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsConveyor Single Flow40202532Petroleum and SolventEvaporationSurface CoatingOperationsMiscellaneous Metal PartsConveyor Single Dip40202533Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsConveyor Single Spray40202534Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsConveyor Two Coat, Flow and Spray40202535Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsConveyor Two Coat, Dip and Spray40202536Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsConveyor Two Coat, Spray40202537Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsManual Two Coat, Spray and Air Dry40202542Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsSingle Coat Application: Spray, High SolidsJanuary 2012Final ReportA-23Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40202543Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsSingle Coat Application: Spray, Water-borne40202544Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsSingle Coat Application: Dip40202545Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsSingle Coat Application: Flow Coat40202546Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsSingle Coat Application: Flashoff40202599Petroleum and SolventEvaporationSurface Coating OperationsMiscellaneous Metal PartsOther Not Classified2401060000 - Solvent Utilization; Surface Coating;Large Appliances: SIC 363; Total: All Solvent Types40201401Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesPrime Coating Operation40201402Petroleum and SolventEvaporationSurface Coating OperationsLargeAppliancesCleaning/Pretreatment40201403Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesCoating Mixing40201404Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesCoating Storage40201405Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesEquipment Cleanup40201406Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesTopcoat Spray40201410Petroleum and SolventEvaporationSurfaceCoating OperationsLarge AppliancesPrime Coat Flashoff40201411Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesTopcoat Flashoff40201431Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesCoating Line: General40201432Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesPrime Air Spray40201433Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesPrime Electrostatic Spray40201434Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesPrime Flow Coat40201435Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesPrime Dip Coat40201436Petroleum and SolventEvaporationSurfaceCoating OperationsLarge AppliancesPrime Electro-deposition40201437Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesTop Air Spray40201438Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesTopElectrostatic Spray40201499Petroleum and SolventEvaporationSurface Coating OperationsLarge AppliancesOther Not ClassifiedJanuary 2012Final ReportA-24Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2401065000 - Solvent Utilization; Surface Coating;Electronic and Other Electrical: SIC 36 – 363; Total: All Solvent Types40203001Petroleum and SolventEvaporationSurface Coating OperationsSemiconductorsSpecify Solvent2401070000 - Solvent Utilization; Surface Coating;Motor Vehicles: SIC 371; Total: All Solvent Types40201601Petroleum and SolventEvaporationSurfaceCoating OperationsAutomobiles and Light TrucksPrime Application/Electo-deposition/Dip/SprayInclude unless NAICS =8111*40201602Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksCleaning/PretreatmentIncludeunless NAICS =8111*40201603Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksCoating MixingInclude unless NAICS =8111*40201604Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles andLight TrucksCoating StorageInclude unless NAICS =8111*40201605Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksEquipment CleanupInclude unless NAICS =8111*40201606Petroleum and SolventEvaporationSurfaceCoating OperationsAutomobiles and Light TrucksTopcoat OperationInclude unless NAICS =8111*40201607Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksSealersInclude unless NAICS =8111*40201608Petroleum andSolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksDeadenersInclude unless NAICS =8111*40201609Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksAnti-corrosion PrimingInclude unlessNAICS =8111*40201619Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Surfacing OperationInclude unless NAICS =8111*40201620Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles andLight TrucksRepair Topcoat Application AreaInclude unless NAICS =8111*40201621Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Solvent-borne-AutomobilesInclude unless NAICS =8111*40201622Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Electro-deposition-AutomobilesInclude unless NAICS =8111*40201623Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles andLight TrucksGuide Coating: Solvent-borne-AutomobilesInclude unless NAICS =8111*40201624Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksGuide Coating: Water-borne-AutomobilesInclude unless NAICS =8111*40201625Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Solvent-borne-AutomobilesInclude unless NAICS =8111*40201626Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles andLight TrucksTopcoat: Water-borne-AutomobilesInclude unless NAICS =8111*40201627Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Solvent-borne-Light TrucksInclude unless NAICS =8111*40201628Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksPrime Coating: Electro-deposition-Light TrucksInclude unless NAICS =8111*40201629Petroleum and SolventEvaporationSurface Coating OperationsAutomobilesand Light TrucksGuide Coating: Solvent-borne-Light TrucksInclude unless NAICS =8111*40201630Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksGuide Coating: Water-borne-Light TrucksInclude unless NAICS =8111*January 2012Final ReportA-25Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40201631Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksTopcoat: Solvent-borne-Light TrucksInclude unless NAICS =8111*40201632Petroleum and SolventEvaporationSurface Coating OperationsAutomobilesand Light TrucksTopcoat: Water-borne-Light TrucksInclude unless NAICS =8111*40201699Petroleum and SolventEvaporationSurface Coating OperationsAutomobiles and Light TrucksOther Not ClassifiedInclude unless NAICS =8111*2401075000 - Solvent Utilization; Surface Coating;Aircraft: SIC 372; Total: All Solvent Types40202401Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftPrime Coating Operation40202402Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftCleaning/Pretreatment40202403Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftCoating Mixing40202404Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftCoating Storage40202405Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftEquipment Cleanup40202406Petroleum and SolventEvaporationSurface Coating OperationsLarge AircraftTopcoat Operation40202499Petroleum and SolventEvaporationSurfaceCoating OperationsLarge AircraftOther Not Classified2401080000 - Solvent Utilization; Surface Coating;Marine: SIC 373; Total: All Solvent Types40202301Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsPrime Coating Operation40202302Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsCleaning/Pretreatment40202303Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsCoating Mixing40202304Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsCoating Storage40202305Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsEquipment Cleanup40202306Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsTopcoatOperation40202399Petroleum and SolventEvaporationSurface Coating OperationsLarge ShipsOther Not Classified2401090000 - Solvent Utilization; Surface Coating;Miscellaneous Manufacturing; Total: All Solvent Types40202201Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsCoating Operation40202202Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsCleaning/Pretreatment40202203Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsCoating Mixing40202204Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsCoating StorageJanuary 2012Final ReportA-26Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40202205Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsEquipment Cleanup40202206Petroleumand SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Baseline Coating Mix40202207Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Low Solids Solvent-borne Coating40202208Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Medium Solids Solvent-borne Coating40202209Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: High Solids Coating (25% Efficiency)40202210Petroleumand SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: High Solids Solvent-borne Coating (40%Efficiency)40202211Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Water-borne Coating40202212Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Low Solids Solvent-borne EMI/RFI ShieldingCoating40202213Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Higher Solids Solvent-borne EMI/RFI ShieldingCoating40202214Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Water-borne EMI/RFI Shielding Coating40202215Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsBusiness: Zinc Arc Spray40202220Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsPrime Coat Application40202229Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsPrime Coat Flashoff40202230Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsColor Coat Application40202239Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsColor Coat Flashoff40202240Petroleum and SolventEvaporationSurfaceCoating OperationsPlastic PartsTopcoat/Texture Coat Application40202249Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsTopcoat/Texture Coat Flashoff40202250Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsEMI/RFI Shielding Coat Application40202259Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsEMI/RFI Shielding Coat Flashoff40202270Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsSanding/Grit Blasting Prior to EMI/RFI Shielding CoatApplication40202280Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsMaskant Application40202299Petroleum and SolventEvaporationSurface Coating OperationsPlastic PartsOther Not Classified2415000000 - Solvent Utilization; Degreasing; All Processes/All Industries; Total: All Solvent Types40100201Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingStoddard (Petroleum Solvent): Open-top VaporDegreasingJanuary 2012Final ReportA-27Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40100202Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasing1,1,1-Trichloroethane (Methyl Chloroform): Open-topVapor Degreasing40100203Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingPerchloroethylene: Open-top Vapor Degreasing40100204Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingMethylene Chloride: Open-top Vapor Degreasing40100205Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichloroethylene: Open-top Vapor Degreasing40100206Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingToluene: Open-top Vapor Degreasing40100207Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichlorotrifluoroethane (Freon): Open-top VaporDegreasing40100208Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingChlorosolve: Open-top Vapor Degreasing40100209Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingButyl Acetate: Open-top Vapor Degreasing40100215Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingEntire Unit: Open-top Vapor Degreasing40100216Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingDegreaser: Entire Unit40100217Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingEntire Unit40100221Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingStoddard (Petroleum Solvent): ConveyorizedVaporDegreasing40100222Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasing1,1,1-Trichloroethane (Methyl Chloroform):ConveyorizedVapor Degreaser40100223Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingPerchloroethylene: Conveyorized Vapor Degreasing40100224Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingMethylene Chloride: Conveyorized Vapor Degreasing40100225Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichloroethylene: Conveyorized Vapor Degreasing40100235Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingEntire Unit: with Vaporized Solvent: Conveyorized VaporDegreasing40100236Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingEntire Unit: with Non-boiling Solvent: Conveyorized VaporDegreasing40100251Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingStoddard (Petroleum Solvent): General Degreasing Units40100252Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasing1,1,1-Trichloroethane (Methyl Chloroform): GeneralDegreasing Units40100253Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingPerchloroethylene:General Degreasing Units40100254Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingMethylene Chloride: General Degreasing Units40100255Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichloroethylene:General Degreasing Units40100256Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingToluene: General Degreasing UnitsJanuary 2012Final ReportA-28Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40100257Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichlorotrifluoroethane(Freon): General DegreasingUnits40100258Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingTrichlorofluoromethane: General Degreasing Units40100259Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasing1,1,1-Trichloroethane (Methyl Chloroform): GeneralDegreasing Units40100295Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingOther Not Classified: General Degreasing Units40100296Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingOther Not Classified: General Degreasing Units40100297Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingOther Not Classified: Open-top Vapor Degreasing40100298Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingOther Not Classified: Conveyorized Vapor Degreasing40100299Petroleum and SolventEvaporationOrganic Solvent EvaporationDegreasingOther Not Classified: Open-top Vapor Degreasing40100301Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingMethanol40100302Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingMethylene Chloride40100303Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingStoddard (Petroleum Solvent)40100304Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingPerchloroethylene40100305Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/Stripping1,1,1-Trichloroethane (Methyl Chloroform)40100306Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingTrichloroethylene40100307Petroleum andSolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingIsopropyl Alcohol40100308Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingMethyl Ethyl Ketone40100309Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingFreon40100310Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingAcetone40100311Petroleum and SolventEvaporationOrganic SolventEvaporationCold Solvent Cleaning/StrippingGlycol Ethers40100335Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingEntire Unit40100336Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingDegreaser: Entire Unit40100398Petroleum and SolventEvaporationOrganic Solvent EvaporationCold Solvent Cleaning/StrippingOther Not Classified40100399Petroleum and SolventEvaporationOrganic Solvent EvaporationColdSolvent Cleaning/StrippingOther Not Classified40100401Petroleum and SolventEvaporationOrganic Solvent EvaporationKnit Fabric Scouring withChlorinated SolventPerchloroethyleneJanuary 2012Final ReportA-29Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2425000000 - Solvent Utilization; Graphic Arts; AllProcesses; Total: All Solvent Types40500101Petroleum and SolventEvaporationPrinting/PublishingDryingDryer40500199Petroleum and SolventEvaporationPrinting/PublishingDryingDryer40500201Petroleum and SolventEvaporationPrinting/PublishingGeneralLetterPress: 275140500202Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (Kerosene)40500203Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvents (Mineral Solvents)40500211Petroleum andSolventEvaporationPrinting/PublishingGeneralLetter Press: 275140500212Petroleum and SolventEvaporationPrinting/PublishingGeneralPrinting: Letter Press40500215Petroleum and SolventEvaporationPrinting/PublishingGeneralLetterpress:Cleaning Solution40500301Petroleum and SolventEvaporationPrinting/PublishingGeneralPrinting: Flexographic40500302Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (Carbitol)40500303Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (Cellosolve)40500304Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (Ethyl Alcohol)40500305Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (Isopropyl Alcohol)40500306Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent (n-Propyl Alcohol)40500307Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent(Naphtha)40500311Petroleum and SolventEvaporationPrinting/PublishingGeneralPrinting: Flexographic40500312Petroleum and SolventEvaporationPrinting/PublishingGeneralPrinting: Flexographic40500314Petroleum and SolventEvaporationPrinting/PublishingGeneralPrinting: Flexographic: Propyl Alcohol Cleanup40500315Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Steam: Water-based40500316Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Steam: Water-based40500317Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Steam: Water-based40500318Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Steam: Water-based in Ink40500319Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Steam: Water-based Ink StorageJanuary 2012Final ReportA-30Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40500401Petroleum and SolventEvaporationPrinting/PublishingGeneralLithographic: 275240500411Petroleum and SolventEvaporationPrinting/PublishingGeneralLithographic: 275240500412Petroleum and SolventEvaporationPrinting/PublishingGeneralLithographic: 275240500413Petroleum and SolventEvaporationPrinting/PublishingGeneralLithographic: Isopropyl Alcohol Cleanup40500414Petroleum and SolventEvaporationPrinting/PublishingGeneralFlexographic: Propyl Alcohol Cleanup40500415Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Dampening Solution with AlcoholSubstitute40500416Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Dampening Solution with High SolventContent40500417Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Cleaning Solution: Water-based40500418Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Dampening Solution with IsopropylAlcohol40500421Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Heatset Ink Mixing40500422Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Heatset Solvent Storage40500431Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Nonheated Lithographic Inks40500432Petroleum andSolventEvaporationPrinting/PublishingGeneralOffset Lithography: Nonheated Lithographic Inks40500433Petroleum and SolventEvaporationPrinting/PublishingGeneralOffset Lithography: Nonheated Lithographic Inks40500501Petroleum and SolventEvaporationPrinting/PublishingGeneralGravure: 275440500502Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Dimethylformamide40500503Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Ethyl Acetate40500506Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Methyl Ethyl Ketone40500507Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Methyl Isobutyl Ketone40500510Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Toluene40500511Petroleum and SolventEvaporationPrinting/PublishingGeneralGravure: 275440500512Petroleum and SolventEvaporationPrinting/PublishingGeneralGravure: 275440500513Petroleum and SolventEvaporationPrinting/PublishingGeneralGravure: 275440500514Petroleum and SolventEvaporationPrinting/PublishingGeneralGravure: Cleanup SolventJanuary 2012Final ReportA-31Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40500597Petroleum and SolventEvaporationPrinting/PublishingGeneralOther Not Classified40500598Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Thinning Solvent: Other Not Specified40500599Petroleum and SolventEvaporationPrinting/PublishingGeneralInk ThinningSolvent: Other Not Specified40500601Petroleum and SolventEvaporationPrinting/PublishingGeneralInk Mixing40500701Petroleum and SolventEvaporationPrinting/PublishingGeneralSolvent Storage40500801Petroleum and SolventEvaporationPrinting/PublishingGeneralScreen Printing40500802Petroleum and SolventEvaporationPrinting/PublishingGeneralFugitive Emissions: Cleaning Rags40500811Petroleum and SolventEvaporationPrinting/PublishingGeneralScreen Printing40500812Petroleum and SolventEvaporationPrinting/PublishingGeneralScreen Printing40588801Petroleum and SolventEvaporationPrinting/PublishingFugitive EmissionsSpecify in Comments Field40588802Petroleum and SolventEvaporationPrinting/PublishingFugitive EmissionsSpecify in Comments Field40588803Petroleum and SolventEvaporationPrinting/PublishingFugitive EmissionsSpecify in Comments Field40588804Petroleum and SolventEvaporationPrinting/PublishingFugitive EmissionsSpecify inComments Field40588805Petroleum and SolventEvaporationPrinting/PublishingFugitive EmissionsSpecify in Comments FieldJanuary 2012Final ReportA-32Table A-6. Gasoline Distribution Crosswalk for Point Source SubtractionsPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2501050120 - Storage and Transport; Petroleum and Petroleum Product Storage; Bulk Terminals: All Evaporative Losses; Gasoline40400101Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13:Breathing Loss (67000 BblCapacity) - Fixed Roof Tank40400102Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Breathing Loss (67000 BblCapacity) - Fixed Roof Tank40400103Petroleum andSolvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Breathing Loss (67000 Bbl.Capacity) - Fixed Roof Tank40400104Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasolineRVP 13: Breathing Loss (250000 BblCapacity)-Fixed Roof Tank40400105Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Breathing Loss (250000 BblCapacity)-Fixed Roof Tank40400106Petroleumand Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Breathing Loss (250000 BblCapacity) - Fixed Roof Tank40400107Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13: Working Loss (Diam.Independent) - Fixed Roof Tank40400108Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Working Loss (Diam.Independent) - Fixed Roof Tank40400109Petroleumand Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Working Loss (Diam.Independent) - Fixed Roof Tank40400110Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasolineRVP 13: Standing Loss (67000 BblCapacity)-Float. Roof Tank40400111Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss (67000 BblCapacity)-Float. Roof Tank40400112Petroleum andSolvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss (67000 BblCapacity)- Floating Roof Tank40400113Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasolineRVP 13: Standing Loss (250000 BblCap.) - Floating Roof Tank40400114Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss (250000 BblCap.) - Floating Roof Tank40400115Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss (250000 BblCap.) - Floating Roof Tank40400116Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasolineRVP 13/10/7: Withdrawal Loss (67000Bbl Cap.) - Float Rf Tnk40400117Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13/10/7: Withdrawal Loss(250000 Bbl Cap.) - Float Rf Tnk40400118Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13: Filling Loss (10500 Bbl Cap.)- Variable Vapor Space40400119Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Filling Loss (10500 Bbl Cap.)- Variable Vapor Space40400120Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Filling Loss (10500 Bbl Cap.)-Variable Vapor Space40400131Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13: Standing Loss-Ext. FloatingRoof w/ Primary Seal40400132Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss-Ext. FloatingRoof w/ Primary SealJanuary 2012Final ReportA-33Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40400133Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss-ExternalFloating Roof w/ Primary Seal40400141Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400142Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400143Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400148Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 13/10/7: Withdrawal Loss-Ext.Float Roof (Pri/Sec Seal)40400150Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsMiscellaneous Losses/Leaks: Loading Racks40400151Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsValves, Flanges, and Pumps40400152Petroleum and Solvent EvaporationPetroleum Liquids Storage(non-Refinery)Bulk TerminalsVapor Collection Losses40400153Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsVapor Control Unit Losses40400161Petroleum and Solvent EvaporationPetroleum Liquids Storage(non-Refinery)Bulk TerminalsGasoline RVP 13: Standing Loss-Int. FloatingRoof w/ Primary Seal40400162Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss-Int. FloatingRoof w/ Primary Seal40400163Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss-InternalFloating Roof w/ Primary Seal40400171Petroleum and Solvent EvaporationPetroleum Liquids Storage(non-Refinery)Bulk TerminalsGasoline RVP 13: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400172Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 10: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400173Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk TerminalsGasoline RVP 7: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400178Petroleum and Solvent EvaporationPetroleum Liquids Storage(non-Refinery)Bulk TerminalsGasoline RVP 13/10/7: Withdrawal Loss-Int.Float Roof (Pri/Sec Seal)2501055120 - Storage and Transport; Petroleum and Petroleum Product Storage; Bulk Plants: All Evaporative Losses; Gasoline40400201Petroleum andSolvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Breathing Loss (67000 BblCapacity) - Fixed Roof Tank40400202Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP10: Breathing Loss (67000 BblCapacity) - Fixed Roof Tank40400203Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Breathing Loss (67000 Bbl.Capacity) - Fixed Roof Tank40400204Petroleum andSolvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Working Loss (67000 Bbl.Capacity) - Fixed Roof Tank40400205Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Working Loss (67000 Bbl.Capacity) - Fixed Roof Tank40400206Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Working Loss (67000 Bbl.Capacity) - Fixed Roof Tank40400207Petroleum and SolventEvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Standing Loss (67000 BblCap.) - Floating Roof TankJanuary 2012Final ReportA-34Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40400208Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10:Standing Loss (67000 BblCap.) - Floating Roof Tank40400209Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Standing Loss (67000 BblCap.) - Floating Roof Tank40400210Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13/10/7: Withdrawal Loss (67000Bbl Cap.) - Float Rf Tnk40400211Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: FillingLoss (10500 Bbl Cap.)- Variable Vapor Space40400212Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Filling Loss (10500 Bbl Cap.)- Variable Vapor Space40400213Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Filling Loss (10500 Bbl Cap.)-Variable Vapor Space40400231Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Standing Loss-Ext. FloatingRoof w/ Primary Seal40400232Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Standing Loss-Ext. FloatingRoof w/ Primary Seal40400233Petroleum and Solvent EvaporationPetroleumLiquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Standing Loss-ExternalFloating Roof w/ Primary Seal40400241Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400242Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400243Petroleum and Solvent EvaporationPetroleum LiquidsStorage (non-Refinery)Bulk PlantsGasoline RVP 7: Standing Loss-Ext. FloatingRoof w/ Secondary Seal40400248Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10/13/7: Withdrawal Loss-Ext.Float Roof (Pri/Sec Seal)40400250Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsLoading Racks40400251Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsValves, Flanges, and Pumps40400252Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsMiscellaneous Losses/Leaks: Vapor CollectionLosses40400253Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsMiscellaneous Losses/Leaks: Vapor Control UnitLosses40400261Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Standing Loss-Int. FloatingRoof w/ Primary Seal40400262Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Standing Loss-Int. FloatingRoof w/ Primary Seal40400263Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: StandingLoss-InternalFloating Roof w/ Primary Seal40400271Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 13: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400272Petroleum and SolventEvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400273Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 7: Standing Loss-Int. FloatingRoof w/ Secondary Seal40400278Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsGasoline RVP 10/13/7: Withdrawal Loss-Int.Float Roof (Pri/Sec Seal)January 2012Final ReportA-35Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments40400401Petroleum and SolventEvaporationPetroleum Liquids Storage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 13: Breathing Loss40400402Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 13: WorkingLoss40400403Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 10: Breathing Loss40400404Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 10: Working Loss40400405Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 7: Breathing Loss40400406Petroleum and Solvent EvaporationPetroleum LiquidsStorage (non-Refinery)Petrol Prods-UndergrdTanksGasoline RVP 7: Working Loss40600101Petroleum and Solvent EvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline: Splash Loading **40600126Petroleum and SolventEvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline: Submerged Loading **40600131Petroleum and Solvent EvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline: Submerged Loading (Normal Service)40600136Petroleum and Solvent EvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline: Splash Loading (Normal Service)40600141Petroleum and Solvent EvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline:Submerged Loading (BalancedService)40600144Petroleum and Solvent EvaporationTransport. & Marketing of PetrolProductTank Cars/TrucksGasoline: Splash Loading (Balanced Service)40600147Petroleum and Solvent EvaporationTransportation andMarketing ofPetroleum ProductsTank Cars/TrucksGasoline: Submerged Loading (Clean Tanks)2501060051 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Submerged Filling40600302Petroleum and SolventEvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage ISubmerged Filling w/o Controls40600305Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage IUnloading **Emissions from SCC 40600305allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600399Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage INot Classified **Emissions from SCC 40600399allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600702Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage ISubmerged Filling w/o ControlsJanuary 2012Final ReportA-36Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2501060052 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Splash Filling40600301Petroleum andSolvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage ISplash Filling40600305Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage IUnloading **Emissions from SCC 40600305allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600399Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasolineRetail Operations- Stage INot Classified **Emissions from SCC 40600399allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600701Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage ISplash Filling2501060053 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Balanced Submerged Filling40600305Petroleum and SolventEvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage IUnloading **Emissions from SCC 40600305allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600306Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage IBalanced Submerged Filling40600399Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage INot Classified **Emissions from SCC 40600399allocated to 2501060051,2501060052, and 2501060053based on proportion of totalemissions for these SCCs.40600706Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage IBalanced Submerged Filling2501060100 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 2: Total40600401Petroleum and SolventEvaporationTransportation and Marketing ofPetroleum ProductsFilling Vehicle Gas Tanks-Stage IIVapor Loss w/o Controls40600402Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsFilling Vehicle Gas Tanks-Stage IILiquid Spill Loss w/o Controls40600403Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsFilling Vehicle Gas Tanks-Stage IIVapor Loss w/o Controls40600499Petroleum and Solvent EvaporationTransportation andMarketing ofPetroleum ProductsFilling Vehicle Gas Tanks-Stage IINot Classified **40600601Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage IIVapor Loss w/o Controls40600602Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage IILiquid Spill Loss w/o Controls40600603Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer (Corporate)Fleet Refueling - Stage IIVapor Loss w/controlsJanuary 2012Final ReportA-37Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2501060201 – Storage and Transport; Petroleum and Petroleum Product Transport; Gasoline Service Stations; Underground Tank: Breathing and Emptying40600307Petroleum andSolvent EvaporationTransportation and Marketing ofPetroleum ProductsGasoline Retail Operations- Stage IUnderground Tank Breathing and Emptying40600707Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsConsumer(Corporate)Fleet Refueling - Stage IUnderground Tank Breathing and Emptying2505030120 - Storage and Transport; Petroleum and Petroleum Product Transport; Truck; Gasoline40400154Petroleum and Solvent EvaporationPetroleum Liquids Storage(non-Refinery)Bulk TerminalsTank Truck Vapor Leaks40400254Petroleum and Solvent EvaporationPetroleum Liquids Storage (non-Refinery)Bulk PlantsTank Truck Vapor Losses40600162Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsTank Cars and TrucksGasoline: Loaded with Fuel (Transit Losses)40600163Petroleum and Solvent EvaporationTransportation and Marketing ofPetroleum ProductsTank Cars and TrucksGasoline: Return with Vapor (Transit Losses)January 2012Final ReportA-38Table A-7. Mining and Quarrying Crosswalk for Point Source SubtractionPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2325000000 – Industrial Processes; Mining and Quarrying: SIC 14; All Processes; Total30302401Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Primary Crushing: Low Moisture Ore30302402Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Secondary Crushing: Low Moisture Ore30302403Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Tertiary Crushing: Low Moisture Ore30302404Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Material Handling: Low Moisture Ore30302405Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Primary Crushing: High Moisture Ore30302406Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Secondary Crushing: High Moisture Ore30302407Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Tertiary Crushing: High Moisture Ore30302408Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Material Handling: High Moisture Ore30302409Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Dry Grinding with Air Conveying30302410Industrial ProcessesPrimary Metal ProductionMetal Mining (General Processes)Dry Grinding without Air Conveying30302411Industrial ProcessesPrimaryMetal ProductionMetal Mining (General Processes)Ore Drying30303101Industrial ProcessesPrimary Metal ProductionLeadbearing Ore Crushing and GrindingLead Ore w/ 5.1% Lead Content30303102Industrial ProcessesPrimary Metal ProductionLeadbearingOre Crushing and GrindingZinc Ore w/ 0.2% Lead Content30303103Industrial ProcessesPrimary Metal ProductionLeadbearing Ore Crushing and GrindingCopper Ore w/ 0.2% Lead Content30303104Industrial ProcessesPrimary Metal ProductionLeadbearing OreCrushing and GrindingLead-Zinc Ore w/ 2% Lead Content30303105Industrial ProcessesPrimary Metal ProductionLeadbearing Ore Crushing and GrindingCopper-Lead Ore w/ 2% Lead Content30303106Industrial ProcessesPrimary Metal ProductionLeadbearingOre Crushing and GrindingCopper-Zinc Ore w/ 0.2% Lead Content30303107Industrial ProcessesPrimary Metal ProductionLeadbearing Ore Crushing and GrindingCopper-Lead-Zinc w/ 2% Lead Content30501001Industrial ProcessesMineral ProductsCoal Mining,Cleaning, and Material Handling (See 305310)Fluidized Bed30501002Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Flash or Suspension30501003Industrial ProcessesMineral ProductsCoal Mining,Cleaning, and Material Handling (See 305310)Multilouvered30501004Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Rotary30501005Industrial ProcessesMineral ProductsCoal Mining, Cleaning, andMaterial Handling (See 305310)Cascade30501006Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Continuous Carrier30501007Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and MaterialHandling (See 305310)Screen30501008Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Unloading30501009Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)RawCoal Storage30501010Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Crushing30501011Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Coal Transfer30501012Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Screening30501013Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Air Tables30501014IndustrialProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Cleaned Coal Storage30501015Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Loading30501016Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Loading: Clean Coal30501017Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Secondary Crushing30501021Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Overburden Removal30501022Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Drilling/Blasting30501023Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Loading30501024Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Hauling30501030Industrial ProcessesMineral ProductsCoalMining, Cleaning, and Material Handling (See 305310)Topsoil Removal30501031Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Scrapers: Travel Mode30501032Industrial ProcessesMineral ProductsCoalMining, Cleaning, and Material Handling (See 305310)Topsoil Unloading30501033Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Overburden30501034Industrial ProcessesMineral ProductsCoal Mining,Cleaning, and Material Handling (See 305310)Coal Seam: DrillingJanuary 2012Final ReportA-39Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30501035Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Blasting: Coal Overburden30501036Industrial ProcessesMineral ProductsCoalMining, Cleaning, and Material Handling (See 305310)Dragline: Overburden Removal30501037Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Truck Loading: Overburden30501038Industrial ProcessesMineralProductsCoal Mining, Cleaning, and Material Handling (See 305310)Truck Loading: Coal30501039Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Hauling: Haul Trucks30501040Industrial ProcessesMineralProductsCoal Mining, Cleaning, and Material Handling (See 305310)Truck Unloading: End Dump-Coal30501041Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Truck Unloading: Bottom Dump-Coal30501042Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Truck Unloading: Bottom Dump-Overburden30501043Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Open Storage Pile: Coal30501044Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Train Loading: Coal30501045Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Bulldozing: Overburden30501046Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Bulldozing: Coal30501047Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Grading30501048Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Overburden Replacement30501049Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)WindErosion: Exposed Areas30501050Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Vehicle Traffic: Light/Medium Vehicles30501051Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and MaterialHandling (See 305310)Surface Mining Operations: Open Storage Pile:Spoils30501060Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Surface Mining Operations: Primary Crusher30501061Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Surface Mining Operations: Secondary Crusher30501062Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Surface Mining Operations: Screens30501090Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Haul Roads: General30501099Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305310)Other NotClassified30501640Industrial ProcessesMineral ProductsLime ManufactureVehicle Traffic30501650Industrial ProcessesMineral ProductsLime ManufactureQuarrying Raw Limestone30502009Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305320)Blasting: General30502010Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305320)Drilling30502018Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305320)Drillingwith Liquid Injection30502020Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305320)Drilling30502513Industrial ProcessesMineral ProductsConstruction Sand and GravelExcavating30502514Industrial ProcessesMineralProductsConstruction Sand and GravelDrilling and Blasting30503101Industrial ProcessesMineral ProductsAsbestos MiningSurface Blasting30503102Industrial ProcessesMineral ProductsAsbestos MiningSurface Drilling30503103Industrial ProcessesMineral ProductsAsbestos MiningCobbing30503108Industrial ProcessesMineral ProductsAsbestos MiningOverburden Stripping30503109Industrial ProcessesMineral ProductsAsbestos MiningVentilation of Process Operations30503199IndustrialProcessesMineral ProductsAsbestos MiningOther Not Classified30504001Industrial ProcessesMineral ProductsMining and Quarrying of Nonmetallic MineralsOpen Pit Blasting30504002Industrial ProcessesMineral ProductsMining and Quarrying ofNonmetallic MineralsOpen Pit Drilling30504003Industrial ProcessesMineral ProductsMining and Quarrying of Nonmetallic MineralsOpen Pit Cobbing30504010Industrial ProcessesMineral ProductsMining and Quarrying of Nonmetallic MineralsUndergroundVentilation30504024Industrial ProcessesMineral ProductsMining and Quarrying of Nonmetallic MineralsOverburden Stripping30504101Industrial ProcessesMineral ProductsClay processing: KaolinMining30504201Industrial ProcessesMineral ProductsClay processing: Ball clayMining30504301Industrial ProcessesMineral ProductsClay processing: Fire clayMining30504401Industrial ProcessesMineral ProductsClay processing: BentoniteMining30504501Industrial ProcessesMineral ProductsClayprocessing: Fullers earthMining30504601Industrial ProcessesMineral ProductsClay processing: Common clay and shale, NECMining30531001Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Fluidized BedJanuary 2012Final ReportA-40Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30531002Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Flash or Suspension30531003Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Multilouvered30531004Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Rotary30531005Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Cascade30531006Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Continuous Carrier30531007Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Screen30531008Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Unloading30531009Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Raw Coal Storage30531010Industrial ProcessesMineral ProductsCoal Mining,Cleaning, and Material Handling (See 305010)Crushing30531011Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Coal Transfer30531012Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Screening30531013Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Air Tables30531014Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See305010)Cleaned Coal Storage30531015Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Loading30531016Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Loading: Clean Coal30531017Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Secondary Crushing30531090Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Haul Roads: General30531099Industrial ProcessesMineral ProductsCoal Mining, Cleaning, and Material Handling (See 305010)Other Not Classified30532009Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305020 for diff.units)Blasting: General30532010Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305020 for diff. units)Drilling30532011Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305020 for diff.units)Hauling30532020Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305020 for diff. units)Drilling30532090Industrial ProcessesMineral ProductsStone Quarrying-Processing (See also 305020 for diff. units)HaulRoads-GeneralJanuary 2012Final ReportA-41Table A-8. Agriculture Production Crosswalk for LivestockPoint SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments2805001100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishingoperations on feedlots (drylots); Confinement30202001Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output30202002Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output2805001200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishingoperations on feedlots (drylots); Manure handling and storage30202001Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output30202002Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpointSCCs based onCMU Model output2805001300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishingoperations on feedlots (drylots); Land applicationof manure30202001Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output30202002Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output2805003100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishingoperations on pasture/range; Confinement30202001Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCsbased onCMU Model output30202002Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsFeedlots: GeneralApportion between nonpoint SCCs based onCMU Model output2805007100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with dry manure management systems; Confinement30202101Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: DryApportion between nonpoint SCCs based onCMU Model output30202102IndustrialProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: DryApportion between nonpoint SCCs based onCMU Model output2805007300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with dry manure management systems; Land application of manure30202101Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: DryApportion between nonpoint SCCs based onCMU Model output30202102Industrial ProcessesFood andAgricultureEggs and Poultry ProductionManure Handling: DryApportion between nonpoint SCCs based onCMU Model output2805008100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Confinement30202105Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: WetApportion between nonpoint SCCs based onCMU Model output30202106Industrial ProcessesFood and AgricultureEggs and PoultryProductionManure Handling: WetApportion between nonpoint SCCs based onCMU Model output2805008200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Manure handling and storage30202105Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: WetApportion between nonpoint SCCs based onCMU Model outputJanuary 2012Final ReportA-42Point SCCSCC1 DESCSCC3 DESCSCC6 DESCSCC8 DESCComments30202106Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManureHandling: WetApportion between nonpoint SCCs based onCMU Model output2805008300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Land application of manure30202105Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: WetApportion between nonpoint SCCs based onCMU Model output30202106Industrial ProcessesFood and AgricultureEggs and Poultry ProductionManure Handling: WetApportionbetween nonpoint SCCs based onCMU Model output2805039100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production - operations with lagoons (unspecified animal age); Confinement30202000Industrial ProcessesFood andAgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpoint SCCs based onCMU Model output2805039200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production - operations with lagoons (unspecified animal age); Manurehandling and storage30202000Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpoint SCCs based onCMU Model output2805039300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production – deep-pit house operations (unspecified animal age); Landapplication of manure30202000Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpoint SCCs based onCMU Model output2805047100 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – deep-pit operations (unspecified animal age); Confinement30202000Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpointSCCs based onCMU Model output2805047300 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – deep-pit operations (unspecified animal age); Land application of manure30202000Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpoint SCCs based onCMU Model output2805053100 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – outdoor operations (unspecified animal age); Confinement30202000Industrial ProcessesFood and AgricultureBeef Cattle FeedlotsSwine FeedlotsApportion between nonpoint SCCs based onCMU Model outputNote: no emissions were identified in the above SCCs within version 1.10a of the SEMAP point source inventory.

# 2007 MOVES2010a On

Emissions Factors for the

Southeastern Modeling Analysis



# and Planning (SEMAP) States

Executive Director, Southeastern

526 Forest Parkway, Suite F

Forest Park, GA 30297

(404) 361

hornback@metro4

AMEC Environment & Infrastructure, Inc.

(352) 333

Alpine Geophysics, LLC

Mark Diblin

Senior Principal



# AMEC Project No.:

Contract No.: S 

# 2007 MOVES2010a On



# - road Mobile Source

Emissions Factors for the

Southeastern Modeling Analysis

Planning (SEMAP) States

Prepared For:

John Hornback

Executive Director, Southeastern States Air Resource Managers, Inc.

526 Forest Parkway, Suite F

Forest Park, GA 30297 

# -6140.

(404) 361 

# -4000, FAX (404) 361-2411

hornback@metro4 

# -sesarm.org

Prepared by:

AMEC Environment & Infrastructure, Inc.



# 404 SW 140 th 

# Terrace

Newberry, FL 32669

(352) 333 

# -6617, FAX (352) 333-6622

wrbarnard@ AMEC.com

and

Alpine Geophysics, LLC



# 2076 Westwood Lane

Eugene, OR 97401

William R. Barnard

Senior Principal



# AMEC Project No.: 

# 6066-09-0326.02

Contract No.: S 

# -2009-06-02

March 21, 2013 

# road Mobile Source

Southeastern Modeling Analysis

Planning (SEMAP) States

States Air Resource Managers, Inc.

William R. Barnard

Senior Principal

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

i AMEC 

# Table of Contents

1.0 INTRODUCTION

.................................................. ................................................... ....................... 4



# 1.1 T HE 

# M OTOR 

# V EHICLE 

# E MISSIONS 

# S IMULATOR 

# (MOVES) ........................................... ....... 4

1.2 MOVES/SMOKE INTERFACE TOOL .............................................. .............................. 4

2.0 COMPONENTS OF THE STUDY

.................................................. ............................................... 6



# 2.1 RH AND 

# RVP S ENSITIVITY 

# E XPERIMENTS



# ................................................... ...................... 6

2.2 E STIMATE 

# MOVES AND 

# SMOKE M ETEOROLOGY



# .................................................. ........... 6

2.3 E STIMATE 

# E MISSIONS 

# F ACTORS 

# U SING 

# MOVES2010 A



# ................................................... .. 6

2.4 E STIMATE 

# E MISSIONS 

# U SING 

# SMOKE ............................................. ................................ 6

2.5 P REPARE 

# E MISSIONS 

# E STIMATES 

# S UMMARIES FROM 

# SMOKE R EPORTS 

# ............................ 7

3.0 RELATIVE HUMIDITY (RH) AND REID VAPOR PRESSURE (RVP)

SENSITIVITY EXPERIMENTS

.................................................. ................................................... ....... 8



# 4.0 ESTIMATE MOVES AND SMOKE METEOROLOGY

.................................................. ........... 11



# 4.1 DATA INPUTS ............................................

................................................... ............. 11

4.2 DATA OUTPUTS ...........................................

................................................... .......... 12

4.3 RUN SCRIPTS ...........................................

................................................... .............. 13

5.0 ESTIMATE EMISSIONS FACTORS USING MOVES2010A

.................................................. . 15



# 5.1 DATA INPUTS ............................................

................................................... ............. 15

5.2 QUALITY ASSURANCE OF THE MOVES INPUTS ............................................ ......... 16

5.3 MOVES DATA IMPORT AND RUN SPECIFICATION SCRIPTS ................................. 16

5.4 QUALITY ASSURANCE OF THE MOVES XML AND C-SHELL SCRIPTS .................. 18

5.5 RUNNING MOVES2010A ........................................

................................................... 18

5.6 DATA OUTPUTS ...........................................

................................................... .......... 18

5.7 GENERATION OF THE SMOKE-READY EMISSIONS FACTORS .............................. 19

5.8 QUALITY ASSURANCE OF THE MOVES OUTPUT EMISSIONS FACTORS ............. 20

6.0 DEVELOPMENT OF THE EMISSIONS ESTIMATES REPORTS .......................................... 23



# 6.1 OVERVIEW OF WORKSHEETS ........................................ ......................................... 23

6.2 OVERVIEW OF EMBEDDED VBA MACROS ............................................ .................. 23

6.3 USER POLL LIST WORKSHEET ......................................... ....................................... 24

6.4 USER-DEFINED REPORTS ........................................... ............................................ 25

6.5 EXECUTION SPEED OF MACROS ............................................ ................................ 25

6.6 EMISSIONS ESTIMATES SUMMARIES ......................................... ............................ 25

7.0 DATA DISK

.................................................. ................................................... ............................. 37



# 8.0 CONCLUSION

.................................................. ................................................... ........................ 41



# 9.0 REFERENCES

.................................................. ................................................... ........................ 43

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

ii AMEC 

# Table of Tables

Table 4-1. Names of representative counties by state and the n umber of counties assigned to

the representative counties.

Table 6-1. Annual on-road mobile source emissions summary by s tate and network from

gasoline fueled vehicles (tons/year).

Table 6-2. Annual on-road mobile source emissions summary by s tate and network from

diesel fueled vehicles (tons/year).

Table 6-3. Annual on-road mobile source emissions summary by s tate and network from

gasoline and diesel fueled vehicles (tons/year).

Table 6-4. Annual on-road mobile source emissions summary by s tate and vehicle category

(tons/year).

Table 6-5. Ozone season day on-road mobile source emissions su mmary by state and vehicle

category (tons/day).

Table 7-1. Description of data disk archive for the SEMAP 2007 MOVES2010a study.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

iii AMEC 

# Table of Figures

Figure 4-1. Overview of the C-shell script to run MET4MOVES. ? ? in the file names refer to

the two letter state abbreviation.

Figure 5-1. Overview of the data inputs and C-shell scripts use d to construct the

MOVES2010a modeling system data import XML and run specification XML

scripts. ?? in the file names refer to the two let ter state abbreviation. SSCCC in

the file names refer to the five digit state-county FIPS identifier for the

representative county.

Figure 5-2. Overview of the SMOKE-MOVESIntegration perl script and input file that was

necessary to extract the emissions factors from the MOVES2010a MySQL output

data bases. SS in the file names refer to the two digit state FIPS identifier.

SSCCC in the file names refer to the five digit sta te-county FIPS identifier for the

representative county. MM in the file names refer to the two digit fuel month

identifier.

Figure 5-3. Running exhaust VOC rate per distance emissions fac tors (g/mile) for the 2007

winter season for light duty diesel vehicles on urb an interstates for Mecklenburg

County, North Carolina by temperature and speed bin

. Figure 5-4. Crankcase start exhaust VOC rate per vehicle emissi ons factors (g/vehicle/hour)

for the 2007 winter season for light duty gasoline vehicles on all road types for

Jefferson County, Alabama by hour and temperature.

Figure 6-1. Percentage contribution by state and fuel to annual on-road mobile source

emissions estimates.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

4 AMEC 

# 1.0 INTRODUCTION

The Southeastern Modeling Analysis and Planning (SE MAP) group requested the development of

on-road mobile source emissions factors for SEMAP s tates using the latest version of MOVES2010

(OTAQ, 2010a, 2010b) and EPA’s MOVES/SMOKE interfac e tool (EPA, 2010). Though the original

proposal called for the development of on-road mobi le source emissions factors for a 2007 base

year and up to three future years, this document de tails how on-road mobile source emissions

factors were estimated for a 2007 base year.

1.1 The Motor Vehicle Emissions Simulator (MOVES)

MOVES2010 is the U.S. EPA’s next generation mobile source emissions model. An important

feature of MOVES2010 is that a user can choose betw een two options to model on-road mobile

source emissions: (1) the Inventory calculation, wh ich estimates emission rates in terms of total

quantity of emissions for a given time period, and (2) the Emission Rate calculation, which estimates

emission rates in terms of grams/mile (i.e., on-net work driving) and grams/vehicle/hour (i.e., offnetwork idling, starts, refueling, parked, and vapo r venting). For purposes of the proposed study, th e

second option (i.e., Emission Rate calculation) was used.

The first rendition of the model was MOVES2010a. T he study team used MOVES2010a for the

entire project, though MOVES2010b did become availa ble about three-quarters of the way through

the study. Based on assurances from EPA’s Office o f Transportation and Air Quality (OTAQ) that

the emissions factors between the two versions of M OVES were identical, SEMAP decided that it

was best to proceed with the use of the first relea se of the model instead MOVES2010b since input

file development for MOVES2010a had already progres sed significantly and to avoid any potential

delays resulting from transitioning to the newest M OVES version. All future references to

MOVES2010 in this document thus refer to MOVES2010a . During the course of the project, the

study team collaborated with project team members f rom the northeast United States, who were also

running MOVES2010a for their purposes, and with OTA Q staff responsible for the development of

MOVES. As the current study effort really turned o ut to be one of the first real-world applications o f

the MOVES modeling system, the work involved a subs tantial shakedown of the MOVES modeling

system. Thus, as a result of the collaborative eff ort, we were able to jointly identify, verify, and offer

suggestions on how to correct errors encountered wh ile running the MOVES modeling system.

The approach to run MOVES2010 for SMOKE was based o n “representative” counties in order to

avoid duplicate, time consuming runs of MOVE2010. Counties that shared the same fuel

parameters, fleet age distribution, and inspection/ maintenance (I/M) programs, among other factors,

were grouped together and a MOVES2010 run was made for a single, representative county.

During SMOKE modeling of the on-road mobile source sector, the MOVES2010 emissions rates for

this representative county were applied to all coun ties in the county group. Each representative

county was modeled at a range of speeds and tempera tures to produce emission rate lookup tables

(grams/mile or grams/vehicle/hour). The approach al lowed any county with unique distributions of

vehicle miles traveled (VMT), vehicle population, r oadway speed, and grid cell temperatures to be

modeled in SMOKE without having to rerun MOVES2010.

1.2 MOVES/SMOKE INTERFACE TOOL

OTAQ, through contractor support, has developed the MOVES/SMOKE Interface Tool to facilitate

the process of using MOVES to create on-road mobile source emissions estimates for use in air

quality modeling. The MOVES/SMOKE Interface Tool i s comprised of scripts that automate the

proper use of the Emission Rate calculations. The S MOKE-MOVES tool provides three major

functions: (1) Meteorological data preprocessor; ( 2) MOVES2010 model processor; and (3) SMOKE

model processor.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

5 AMEC 

# The Meteorological data preprocessor (MET4MOVES) pr epares spatially and temporally averaged

temperatures and relative humidity data to set up t he meteorological input conditions for

MOVES2010 and SMOKE using the Meteorology-Chemistry Interface Processor (MCIP) output files.

The MOVES2010 model processor creates data input fi les (i.e., runspec) for use in MOVES2010

that specifies the characteristics of the particula r scenario to be modeled, and it reformats the

resulting MOVES2010 emission rates lookup tables th at are suitable for input to SMOKE. The

SMOKE postprocessor (MOVESMRG) estimates emissions from on-road mobile sources based on

MOVES2010-based emission rate lookup tables and met eorology data from MET4MOVES.

For purposes of the proposed study, the study team did not run MOVESMRG. Instead, we provided

the outputs from MET4MOVES and the MOVES2010 model processor to SEMAP for their use in

running MOVESMRG. SEMAP then provided the study te am with the SMOKE reports from which

we developed the emissions estimates summaries.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

6 AMEC 

# 2.0 COMPONENTS OF THE STUDY

There were five distinct components to this effort:

• Perform relative humidity (RH) and Reid vapor pres sure (RVP) sensitivity experiments;

• Estimate MOVES and SMOKE meteorology;

• Estimate on-road mobile source emissions factors u sing MOVES2010a;

• Estimate on-road mobile source emissions using SMO KE; and

• Prepare on-road mobile source emissions estimates summaries from SMOKE reports.

The study team (AMEC Environment & Infrastructure, Inc. and Alpine Geophysics, LLC) conducted

all aspects of this project except for the effort r equired to estimate on-road mobile source emissions

using SMOKE, which was conducted by the University of North Carolina. A brief summary is

provided for each component here and is more fully discussed within the body of this report, with the

exception of the component to estimate on-road mobi le source emissions using SMOKE.

2.1 RH and RVP Sensitivity Experiments

MOVES2010a requires as input the choice of fuel mod eling seasons. The modeling seasons are

chosen based on information such as the fuel charac teristics and meteorology. At the time the

project started, MOVES was just being introduced to the modeling community, and it was unclear

how sensitive the model would be to variations in t hese data. As such, SEMAP decided to conduct

two sensitivity experiments involving two of the pa rameters: relative humidity (RH) and Reid vapor

pressure (RVP); to determine how sensitive MOVES em issions estimates were to these parameters.

2.2 Estimate MOVES and SMOKE Meteorology

MOVES and SMOKE require estimates of RH and ambient temperature for each group of counties

associated with a representative county by fuel sea son. The estimates of RH and ambient

temperature for use in MOVES2010a and SMOKE were pr epared using the MET4MOVES

component of the SMOKE-MOVES Integration Tool (EPA, 2010).

2.3 Estimate Emissions Factors Using MOVES2010a

The study team developed the following six files ba sed on information received from SEMAP:

• Fuel formulation;

• Fuel supply;

• VMT;

• Inspection and Maintenance (I/M) program;

• Age distribution; and

• Vehicle population.

These data coupled with the meteorology were input to MOVES2010a, which produced the on-road

mobile source emissions factors. The input data an d the on-road mobile source emissions factors

were subjected to quality assurance review by the s tudy team, the SEMAP QA contractor

(ENVIRON), and representatives from the SEMAP state s.

2.4 Estimate Emissions Using SMOKE

This component was performed by researchers at the University of North Carolina (UNC). Please

refer to other documentation in regards to the deta ils of performing this component of the study.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

7 AMEC 

# 2.5 Prepare Emissions Estimates Summaries from SMOK E Reports

Researchers at UNC provided SMOKE reports to the st udy team for use in our efforts to summarize

the on-road mobile source emissions estimates. The study team developed Excel workbooks with

Visual Basic for Applications (VBA) scripting to fa cilitate the ingestion of the SMOKE reports.

Further, VBA scripts were developed to prepare a nu mber of standard report summaries as well as

to provide a limited ad-hoc reporting capability so that a user of the Excel workbooks could prepare

their own report summaries from the SMOKE reports.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

8 AMEC 

# 3.0 RELATIVE HUMIDITY (RH) AND REID VAPOR PRESSURE (RVP)

SENSITIVITY EXPERIMENTS

MOVES2010a requires the identification of fuel seas ons for purposes of generating emissions

factors. Fuel seasons should be chosen such that t he groupings have similar fuel characteristics

and meteorology. Because the MOVES modeling system was just being introduced to the modeling

community at the start of this study, it was not cl ear how the choice of fuel season might impact the

MOVES2010a results. SEMAP judged that the two crit ical inputs to the choice of how fuel seasons

were chosen were the RH and RVP. Using default dat a supplied with the MOVES modeling system,

MOVES2010a was run in emissions inventory mode for an April and May 2007 weekday to estimate

emissions (tons/day) for CO, NO X 

# , VOC, 

# SO

2 

# , PM 10 

# , and 

# PM 2.5 

# . MOVES2010a was also run using

data supplied by the SEMAP states that was used in- lieu of the MOVES2010a default data for the

same period and pollutants.

The RH sensitivity simulations included the followi ng:

• For April 2007, Mecklenburg County, NC;

a. Base simulation at 48.98% relative humidity fixe d for all hours of the day,

b. Simulation using national defaults (this was for comparison purposes to estimates

derived using the SEMAP states-supplied data),

c. Four sensitivity simulations at + 5% RH and + 10% RH added to the base simulation,

• For May 2007, Mecklenburg County, NC;

a. Base simulation at 55.37% relative humidity fixe d for all hours of the day,

b. Simulation using national defaults (this was for comparison purposes to estimates

derived using the SEMAP states-supplied data), and

c. Four sensitivity simulations at + 5% RH and + 10% RH added to the base simulation.

The results of the RH runs were compiled into an Ex cel workbook (on the data disk

semap/rh_rvp_sensitivity_experiments/37119_2007_04_ ozone_emissions_estimates_RH_comparis

on.xls). The exhaust, evaporative, and total emiss ions estimates for CO, NO X 

# , VOC, 

# SO

2 

# , PM 10 

# , and



# PM 2.5 

# are compiled in the “RH Emissions Summary” workshe et for both gasoline and diesel fueled

vehicles. Further, the percent change in emissions estimates due to a + 5% and + 10% change in RH

from the base simulation (i.e., 49.98% RH for April 2007 and 55.37% RH for May 2007) were

provided. The choice of + 5% and + 10% RH ranges were made by SEMAP and reflect a gros s range of RH changes seen across the year. A summary of t he emissions estimates changes is as follows:

• For diesel and gasoline VOC, 

# SO

2 

# , PM 10 

# and 

# PM 2.5 

# , the emissions differences due to + 10%

RH change are non-existent (PM 10 

# and 

# PM 2.5 

# are not affected by changes in RH) or

negligible ( 

# SO

2 

# has less than a 0.01 tons/day difference in emissi ons which equates to less

than a 1% difference in emissions, and VOC has less than a 0.20 tons/day difference in

emissions which equates to less than a 1% differenc e in emissions whether they are

evaporative or exhaust);

• For diesel CO, the emissions differences are negli gible due to a + 10% RH change (CO has

less than a 0.20 tons/day difference in emissions w hich equates to about a 1% difference in

emissions);

• For gasoline CO, the emissions differences are sma ll due to a + 10% RH change (though CO

has about a 8 tons/day swing in emissions due to + 10% RH change, this equates to less

than + 1.6% overall difference in the emissions);

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

9 AMEC 

# • For diesel NO X 

# , a + 5% RH change results in about a + 0.50 tons/day change in the emissions

which equates to about + 1.5% change in the emissions. At a + 10% RH change, NO X 

# emissions change by about + 1.0 tons/day which equates to about + 3% change in the

emissions.

• For gasoline NO X 

# , a + 5% RH change results in about a + 0.75 tons/day change in the

emissions which equates to about + 1.5% change in the emissions. At a + 10% RH change,

NO X 

# emissions changes show a non-linear response in Ma y 2007 with the range of -0.90

tons/day to +1.7 tons/day change and a more linear response in April 2007 with a + 1.5

tons/day change, which equates to roughly + 3% of the base emissions.

For diesel and gasoline VOC, CO, 

# SO

2 

# , PM 10 

# and 

# PM 2.5 

# , a + 5% RH change or even a + 10% RH

change results in emissions changes that will likel y not impact the air quality modeling results.

However, for NO X



# a + 5% RH change, diesel and gasoline NO X 

# emissions estimates change by

+ 1.25 tons/day (+ 1.35% -- note that an increase in RH results in a d ecrease in NO X 

# ).

The RVP sensitivity simulations included the follow ing:

• For April 2007, Mecklenburg County, NC;

a. Base simulation at 48.98% RH and RVP of 13.5 psi (ran during RH simulation),

b. Two sensitivity simulations where RVP is set to 15.0 psi and 9.0 psi,

• For May 2007, Mecklenburg County, NC;

a. Base simulation at 55.37% RH and RVP of 9.0 psi (ran during RH simulation), and

b. Two sensitivity simulations where RVP is set to 13.5 psi and 7.8 psi.

The choice of the RVP range was made by SEMAP and r eflects the range of RVPs that are seen the

fuels across the SEMAP states. The results of the RVP runs were compiled into the attached Excel

workbook on the data disk

semap/rh_rvp_sensitivity_experiments/37119_2007_04_ ozone_emissions_estimates_RVP_compari

son.xls). The exhaust, evaporative, and total emis sions estimates for CO, NO X 

# , VOC, 

# SO

2 

# , PM 10 

# , and 

# PM 2.5 

# are compiled in the “RH Emissions Summary” workshe et for gasoline fueled vehicles as

diesel is not affected by RVP. Although results fo r April 2007 with RVP values of 15.0, 13.5, and 9.0

psi and for May 2007 with RVP values of 13.5, 9.0 a nd 7.8 psi are compiled in the Excel workbook,

the focus is only on a summary of the comparison fo r April 2007 between RVP values of 15.0 and

13.5 psi and for May 2007 between RVP values of 9.0 and 7.8 psi as those are the RVP values of

interest for the fuel seasons of concern. A summar y of the emissions estimates changes is as

follows:

• For April 2007 for RVP change of 15.0 psi to base 13.5 psi;

a. Exhaust VOC, 

# SO

2 

# , PM 10 

# , and 

# PM 2.5 

# have negligible (VOC) or no change ( 

# SO

2 

# , PM 10 

# , 

# PM 2.5 

# ) due to a change in RVP,

b. CO emissions decrease with decreasing RVP by 25% (~160 tons/day) of the base CO

emissions,

c. NO X 

# emissions decrease with decreasing RVP by about 2% (~1 ton/day) of the base

NO X 

# emissions,

d. Evaporative VOC emissions decrease with decreasi ng RVP by about 50% (~15

tons/day) of the base evaporative VOC emissions,

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

10 AMEC 

# e. Total VOC emissions decrease with decreasing RVP by about 28% (~15 tons/day) of the

base total VOC emissions,

• For May 2007 for RVP change of base 9.0 psi to 7.8 psi;

a. Exhaust VOC, 

# SO

2 

# , PM 10 

# , and 

# PM 2.5 

# have negligible (VOC) or no change ( 

# SO

2 

# , PM 10 

# , 

# PM 2.5 

# ) due to a change in RVP,

b. CO emissions decrease with decreasing RVP by 1.3 % (~6 tons/day) of the base CO

emissions,

c. NO X 

# emissions decrease with decreasing RVP by about 1. 3% (~1 ton/day) of the base

NO X 

# emissions,

d. Evaporative VOC emissions decrease with decreasi ng RVP by about 12% (~2 tons/day)

of the base evaporative VOC emissions, and

e. Total VOC emissions decrease with decreasing RVP by about 5% (~2 tons/day) of the

base total VOC emissions.

The greatest impact to emissions occurs in the RVP change from 15.0 psi to 13.5 psi with CO and

VOC exhibiting definite sensitivity. There is less of an impact to CO and VOC emissions when the

RVP changes from 9.0 psi to 7.8 psi. However, in b oth cases NO X 

# has about a 1.0 ton/day

sensitivity which may be important for modeling and policy purposes.

Though the results of the experiments indicate that there are important sensitivities to changes in RH

and RVP and thus multiple fuel season definitions m ay be in order, SEMAP determined that a

summer (i.e., May through September) and winter (Ja nuary through April and October through

December) were sufficient for the purposes of the s tudy especially given the significant processing

times that are necessary to run MOVES2010a.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

11 AMEC 

# 4.0 ESTIMATE MOVES AND SMOKE METEOROLOGY

4.1 DATA INPUTS

MOVES2010a and SMOKE require estimates of ambient t emperature and relative humidity. The

MET4MOVES component of the SMOKE-MOVES Integration Tool (EPA, 2010) was used to

facilitate the preparation of the MOVES2010a and SM OKE meteorological data sets.

MET4MOVES requires the following primary inputs:

• Representative county cross-reference;

• Fuel month cross-reference;

• Gridded surrogates; and

• Meteorology-Chemistry Interface Processor (MCIP) d ata sets.

The representative county-cross reference file was prepared based on information that was supplied

by SEMAP (Boylan, 2010). Table 4-1 lists the names of the representative counties and the number

of counties assigned to the representative counties . The 926 counties for the SEMAP states were

assigned to one of the 39 representative counties. The complete assignment details can be found in

the SMOKE data files (i.e., mcref_semap_SS_2007.txt where SS is the state abbreviation) located

on the data disk in the directory semap/edss/data_s emap/ge_dat/mcref_files.

Table 4-1. Names of representative counties by sta te and the number of counties assigned to the

representative counties.

State Representative



# County FIPS Code Number of Counties Assigned

Alabama Jefferson 01073 2

Montgomery 01101 65

Florida Escambia 12033 62

Hillsborough 12057 2

Miami-Dade 12086 3

Georgia Barrow 13013 7

Chatham 13051 114

Floyd 13115 25

Fulton 13121 13

Kentucky Bullitt 21029 1

Fayette 21067 114

Jefferson 21111 1

Kenton 21117 3

Oldham 21185 1

Mississippi Hinds 28049 82

North Carolina Cumberland 37051 40

Davidson 37057 1

Duplin 37061 52

Forsyth 37067 1

Guilford 37081 1

Mecklenburg 37119 2

Orange 37135 1

Wake 37183 2

South Carolina Spartanburg 45083 46

Tennessee Davidson 47037 1

Fayette 47047 2

Hamilton 47065 1

K 

# NO X 

# 47093 7

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

12 AMEC 

# State Representative



# County FIPS Code Number of Counties Assigned

Madison 47113 66

Marion 47115 1

Putnam 47141 7

Rutherford 47149 4

Shelby 47157 1

Sullivan 47163 5

Virginia Albemarle 51003 107

Henrico 51087 7

Prince William 51153 10

York 51199 11

West Virginia Kanawha 54039 55



# The fuel month cross-reference file was prepared ba sed on information supplied by SEMAP (Boylan,

2010). Two fuel seasons, summer (i.e., May through September) and winter (January through April

and October through December), were assigned to eac h representative county. The contents of

these data sets can be viewed in the files semap/ed ss/data_semap/ge_dat/fuelmonth_semap_SS.txt

where SS is the state abbreviation.

The gridded surrogates were provided as part of the SMOKE distribution. As recommended in the

User’s Guide (EPA, 2010), surrogates 100 (i.e., pop ulation) and 240 (i.e., total road miles) were

used to derive the representative county meteorolog y by fuel season. The master surrogate data set

can be found in semap/edss/data_semap/ge_dat/ SRGDE SC.MOVES.NC, which points to the actual

surrogate files semap/edss/data_semap/ge_dat/Srg_12 km_MOVES_SEMAP/USA_100_NOFILL.txt

and semap/edss/data_semap/ge_dat/Srg_12km_MOVES_SEM AP/USA_240_FILL.txt.

The MCIP data sets were provided by UNC for each da y in 2007. The UNC-supplied MCIP data

files were post processed to reduce their considera ble size to something that was more

manageable. The post-processed MCIP data sets cont ain only the ambient temperatures at two

meters, the pressure, and the water vapor mixing ra tio (a surrogate for RH) from the first layer of th e modeling domain. The actual MCIP data sets can be found in the directory

semap/edss/data_semap/met with the naming nomenclat ure of METCOMBO_2007DDD where DDD

is the Julian day of the file. All MCIP files are in netCDF structures.

4.2 DATA OUTPUTS

MET4MOVES produces three output data files:

• SMOKE-ready meteorological data file;

• MOVES-ready meteorological file; and

• Log file.

The SMOKE-ready meteorological data set contains th e temperature and relative humidity estimates

by county, fuel season month, and calendar month ne cessary for input to SMOKE. The MOVESready meteorological data set contains the average relative humidity and twenty-four hourly

temperature estimates by representative county, fue l season month, and temperature profile

necessary for input to MOVES. The log file contain s runtime and error messages from a

MET4MOVES run and is useful for diagnosing problems should they occur. Examples of the

meteorological data sets generated by MET4MOVES for this study can be found in

semap/edss/data_semap/met_out/12k. The MOVES-ready files are named

MOVES_12km_2007001-2007365_??.txt, and the SMOKE-re ady files are named

SMOKE_12km_2007001-2007365_??.txt where ?? is the t wo letter state abbreviation.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

13 AMEC 

# 4.3 RUN SCRIPTS

MET4MOVES is run through Linux C-shell command scri pts. Figure 4-1 provides an overview of the

script names and the primary input and output defin itions that are required. Before the user can run

these scripts, the scripts must be modified to acco mmodate the directory structure of the user’s

computer platform. The scripts to run MET4MOVES ar e located in the directory

semap/edss/subsys/smoke/scripts/run_semap and have the naming convention of

run_met4moves.MOVES.semap.??.bat where ?? is the tw o letter state abbreviation. The following

command is an example of how to run the script for Alabama:

% ./run_met4moves.MOVES.semap.AL.bat

This command will produce copious output so it may advisable to capture this output to log files,

which can be viewed at the user’s convenience:

% (./run_met4moves.MOVES.semap.AL.bat > LOG) >& LOG .error

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

14 AMEC 

# Figure 4-1. Overview of the C-shell scripts to run MET4MOVES. ?? in the file names refer to the

two letter state abbreviation.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

15 AMEC 

# 5.0 ESTIMATE EMISSIONS FACTORS USING MOVES2010A

5.1 DATA INPUTS

The study team prepared MOVES2010a input files for thirty-nine (39) representative counties in the

SEMAP domain for two fuel seasons (i.e., winter and summer) for the 2007 base year. The input

files were prepared for use with the emissions rate calculation mode of MOVES2010a.

The effort included converting default MOBILE6.2 in puts to MOVES2010a inputs using the MOBILE6

to MOVES2010 conversion tools (OTAQ, 2010c). We al so integrated MOVES2010a input files that

were developed by a variety of organizations from t he SEMAP states.

For each representative county, the following six f iles were prepared for input to the MOVES2010a

modeling system:

• Fuel formulation;

• Fuel supply;

• VMT;

• Inspection and Maintenance (I/M) program;

• Age distribution; and

• Vehicle population.

MOVES2010a also requires the following input data f iles, the development of which is described

Chapter 4:

• Representative county cross-reference;

• Fuel month cross-reference; and

• MOVES-ready meteorology.

The six files that were developed during this compo nent of the study were based on multiple

exchanges of information between representatives fr om the SEMAP states and the study team.

Each file went through multiple iterations before a final set of data files was prepared for each of t he

thirty-nine representative counties. The formats o f these files are described in EPA (2010).

The fuel formulation file contains the characterist ics of each fuel, gasoline and diesel, used in the

representative county including such parameters as RVP, fuel sulfur content, and ethanol content.

The fuel supply file identifies the specific fuel u sed during each month of the year and the market

share that fuel has for each representative county. The VMT file defines the annual VMT by major

vehicle category for each representative county. T he I/M program file defines the inspection and

maintenance program characteristics for each repres entative county that was in effect during 2007.

If no I/M program was in existence, this file is em pty. The age distribution file contains the fracti on of

vehicles by vehicle category and model year that co mprise the fleet for the base year (i.e., 2007) and

the prior thirty years. The vehicle population con tains the vehicle counts for each of the thirteen

MOVES vehicle categories.

The input data files can be found on the data disk in the directory semap/smoke_moves_input/??

where ?? is the two letter state abbreviation. The naming convention for the input files is as follow s (where SS is the two digit state code [e.g., 01 for Alabama] and CCC is the three digit county code

[e.g., 073 for Jefferson County]):

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

16 AMEC 

# • SSCCC_FuelFormulation.csv;

• SSCCC_FuelSupply.csv;

• SSCCC_HPMSVTypeVMT.csv;

• SSCCC_IMCoverage.csv;

• SSCCC_sourceTypeAgeDistribution.csv; and

• SSCCC_sourceTypePopulation.csv.

5.2 QUALITY ASSURANCE OF THE MOVES INPUTS

The MOVES data input files were delivered to the SE MAP quality assurance contractor and

representatives from the SEMAP states for review an d comment. Though the review of the MOVES

data input files was expected to take only two or t hree iterations, in the end, many iterations were

required over the course of some fifteen months bef ore the MOVES data input files were completely

correct. This was due in part to problems with the MOVES2010a modeling system itself, in part

because the SEMAP states had evolving needs that re quired changes to the data, and in part due to

issues with the study team not initially fully unde rstanding how MOVES2010a ingested data.

5.3 MOVES DATA IMPORT AND RUN SPECIFICATION SCRIPTS

MOVES2010a requires that XML script files be constr ucted in order to run the modeling system.

The SMOKE-MOVES Integration Tool (EPA, 201) provide s the perl script tools necessary to create

the XML scripts to import the data files described in Section 5.1 and the XML scripts to run the

MOVES2010a modeling system. Figure 5-1 provides an overview of the data inputs and scripts that

are necessary to construct the XML files necessary to run the MOVES2010a modeling system.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

17 AMEC 

# Figure 5-1. Overview of the data inputs and C-shel l scripts used to construct the MOVES2010a

modeling system data import XML and run specificati on XML scripts. ?? in the file names refer to

the two letter state abbreviation. SSCCC in the fi le names refer to the five digit state-county FIPS

identifier for the representative county.



# For each representative county, the study team buil t the two input files ??_runcontrol and

??_repcounty. Further, the study team built the C- shell script

smoke_moves_runspec_generator.csh to help automate the process of constructing the XML

scripts. The perl script runspec_generator_v0.31_2 2Mar2011.pl was the most recent script that was

available in the SMOKE-MOVES Integration Tool at th e time this project was proceeding.

In order to run the C-shell script to construct the XML files suitable to run the MOVES2010a

modeling system, the user must modify the two input files, ??_runcontrol and ??_repcounty, to

conform to the layout of his/her computational plat form. The C-shell script is run as follows:

% source smoke_moves_runspec_generator.csh

The output of this is a set of XML data importer sc ripts, XML run specification scripts, C-shell scrip ts,

and CSV files, which are output to the directories specified in Figure 5-1. The CSV files represent

the MOVES-formatted meteorology that is utilized by the XML data importer scripts.

Though the SMOKE-MOVES Integration Tool prepares th e necessary C-shell scripts to run the XML

files, the result of the effort has all representat ive counties being run on one platform. In order t o spread the MOVES2010a runs over multiple machines s o that the runs are computationally more

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

18 AMEC 

# efficient, the study team split the SEMAP_??_2007im porter.csh and SEMAP_??_2007runspec.csh

C-shell scripts into multiple C-shell scripts – one for each representative county; hence, there exist

thirty-nine importer C-shell scripts and thirty-nin e run specification C-shell scripts that could be r un in

parallel on thirty-nine different computational cor es. The naming convention used to identify the spl it

C-shell scripts is as follows:

• SSCCC_importer_MACHINE_CORE.csh; and

• SSCCC_runspec_MACHINE_CORE.csh.

Where SSCC is the five digit FIPS state-county code , MACHINE is the name of the computational

platform, and CORE identifies the surrogate upon wh ich CPU that the C-shell script is to run on the

MACHINE.

5.4 QUALITY ASSURANCE OF THE MOVES XML AND C-SHELL SCRIPTS

The MOVES XML and C-shell scripts were delivered to the SEMAP quality assurance contractor and

representatives from the SEMAP states for review an d comment. Fortunately, the review of the

MOVES XML and C-shell scripts took only two iterati ons. OTAQ, the developer of the MOVES

modeling system, released at least two new versions of the SMOKE-MOVES Integration Tool run

specification perl scripts which were used to repea t the development of the MOVES XML and Cshell scripts descried in Section 5.3.

5.5 RUNNING MOVES2010A

After the XML and C-shell scripts were constructed, it was possible to actually run the MOVES2010a

modeling system. The first step to running the mod eling system was to import the data described in

Section 5.1. Importing of the data was performed b y executing the following command, one each for

the thirty-nine files on the appropriate MACHINE an d CORE:

% (source SSCCC_importer_MACHINE_CORE.csh > LOG) >& LOG.error

The method of running the C-shell script in this ma nner allowed the capture of the copious output

that was generated during the import of data into t he MOVES2010a MySQL data bases, which the

user can view at his/her leisure and was useful for diagnosing problems when they arose.

After all thirty-nine C-shell importer scripts were run, the effort to generate the actual on-road mob ile

source emissions factors was performed. This was a ccomplished by running the following

command, one each for the thirty-nine files on the appropriate MACHINE and CORE:

% (source SSCCC_runspec_MACHINE_CORE.csh > LOG) >& LOG.error

The method of running the C-shell script in this ma nner allowed the capture of the copious output

that was generated during the generation of on-road mobile source emissions factors that were

stored in the MOVES2010a MySQL data bases, which th e user can view at his/her leisure and was

useful for diagnosing problems when they arose.

5.6 DATA OUTPUTS

All MOVES2010a input data bases, which resulted fro m running the C-shell importer scripts, were

stored in MySQL data bases. There are hundreds of input data bases per representative county as

this is a necessary requirement of the MOVES2010a m odeling system so that the range of

meteorological conditions were captured. All MOVES 2010a emissions factors that were created by

running the C-shell run specification scripts were stored in MySQL data bases, one per

representative county for a total of thirty-nine My SQL output data bases. Each MySQL input and

output data base contained multiple data tables. D escriptions of the contents of the MOVES2010a

MySQL data bases can be found in OTAQ (2010a). The resulting MOVES2010a input MySQL data

bases were archived on the data disk in the directo ry semap/2007_MOVES_MySQL_inputs/??

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

19 AMEC 

# where ?? is the two letter state identifier. Simil arly, the resulting MOVES2010a output MySQL data

bases were archived on the data disk in the directo ry semap/2007_MOVES_MySQL_outputs/??

where ?? is the two letter state identifier.

5.7 GENERATION OF THE SMOKE-READY EMISSIONS FACTORS

Until this point, all modeling was performed on Lin ux machines. Due to unresolved difficulties in

getting the emissions factors extracted from the Li nux based MySQL output data bases using the

perl scripts supplied with the SMOKE-MOVES Integrat ion Tool (EPA, 2010), all MySQL output data

bases were transported to a Windows platform where these difficulties were nonexistent.

Figure 5-2 provides an overview of the input file a nd the perl script that was used to extract the

emissions factors from the MySQL output data bases to create the SMOKE-ready emissions factors

files. The study team built the dbFile_SS, where S S is the two digit state FIPS code, which

contained the necessary information to run the SMOK E-MOVES Integration Tool (EPA, 2010)

extraction perl scripts – moves2smkEF_v0.32_24Aug20 11.pl and smkEFsum_v0.2_02Aug2011.pl.

The perl script to extract the MOVES2010a emissions factors from the MySQL output data bases

was run as follows:

% perl moves2smkEF_v0.32_24Aug2011.pl –output all d bFile_SS.inp

where SS is the two digit FIPS state identifier. T he output of this perl script was the SMOKE-ready

emissions factors and was stored in multiple CSV fi les.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

20 AMEC 

# Figure 5-2. Overview of the SMOKE-MOVESIntegration perl script and input file that was

necessary to extract the emissions factors from the MOVES2010a MySQL output data bases. SS

in the file names refer to the two digit state FIPS identifier. SSCCC in the file names refer to the

five digit state-county FIPS identifier for the rep resentative county. MM in the file names refer to

the two digit fuel month identifier.



# 5.8 QUALITY ASSURANCE OF THE MOVES OUTPUT EMISSIONS FACTORS

Excel workbooks with VBA scripts were developed to assist in review of the MOVES2010a

emissions factors. The workbooks are located on th e data disk in the directory

semap/moves_emissions_factors_qa. Users must be fa miliar with the VBA scripting language in

order to utilize these workbooks to facilitate revi ew of other MOVES2010a emissions factors. These

example workbooks contain the CSV files as describe d in Section 5.7 for the states of Alabama and

North Carolina (e.g., worksheet tab ‘rateperdistanc e_smoke_37051_200’). After the CSV files have

been loaded into a worksheet, a VBA script was run to generate graphics of the emissions factors for

each SCC. The graphics provided a quick means of r eviewing the thousands of emissions factors

that were estimated. These workbooks were delivere d to representatives of the SEMAP states and

the SEMAP quality assurance contractor for review.

Figure 5-3 provides an example of the running exhau st VOC rate per distance emissions factors

(g/mile) for the 2007 winter season for light duty diesel vehicles on urban interstates for Mecklenbur g County, North Carolina by temperature and speed bin . Figure 5-4 provides an example of the

crankcase start exhaust VOC rate per vehicle emissi ons factors (g/vehicle/hour) for the 2007 winter

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

21 AMEC 

# season for light duty gasoline vehicles on all road types for Jefferson County, Alabama by hour and

temperature.

Figure 5-3. Running exhaust VOC rate per distance emissions factors (g/mile) for the 2007 winter

season for light duty diesel vehicles on urban inte rstates for Mecklenburg County, North Carolina

by temperature and speed bin.

Figure 5-4. Crankcase start exhaust VOC rate per v ehicle emissions factors (g/vehicle/hour) for

the 2007 winter season for light duty gasoline vehi cles on all road types for Jefferson County,

Alabama by hour and temperature.



# As was expected with any new modeling system, issue s were found in the initial stages of running

the MOVES2010a modeling system in regards to the em issions factors it estimated. The graphics

provided a quick means to identify the issues from which corrections were made to the input data,

and through the help of the MOVES developers, from which corrections were made to the

MOVES2010a modeling system. Indeed, OTAQ, the deve loper of the MOVES modeling system,

continued to make corrections to MOVES2010a as late as the first quarter of 2012. 1

3

5

7

9

11

13

15 0.00E+00 2.00E-01 4.00E-01 6.00E-01 8.00E-01 1.00E+00

5 15 25 35 45 55 65 75 85 95

**speed bin g/mile** 



# temperature (F) 8.00E

- 01

- 1.00E+00

6.00E

- 01

- 8.00E

- 01

4.00E

- 01

- 6.00E

- 01

2.00E

- 01

- 4.00E

- 01

0.00E+00

- 2.00E

- 01

20 40 60 80



# 0 0.005 0.01 0.015 0.02 0.025 0.03 0.035 0.04

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24**temperature (F) g/veh/hr** 



# hour 0.035-0.04

0.03-0.035

0.025-0.03

0.02-0.025

0.015-0.02

0.01-0.015

0.005-0.01

0-0.005

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

22 AMEC 

# Once the emissions factors had been approved by SEM AP, they were delivered to researchers at

the UNC for their use in estimating on-road mobile source emissions using SMOKE. The data that

were delivered to UNC are contained on the data dis k in the directory

semap/moves2smoke_windows. The naming convention o f the zip archives that were delivered to

UNC was ??_2007_MOVES2010a_corrected.zip where ?? i s the two letter state abbreviation.

These archives also contain the input data files an d perl scripts described in Figure 5-2.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

23 AMEC 

# 6.0 DEVELOPMENT OF THE EMISSIONS ESTIMATES REPORTS

Researchers at UNC delivered to the study team the SMOKE reports that were output by the

SMOKE modeling system. In order to better utilize these data, Excel workbooks with VBA scripts

were developed to ingest the SMOKE reports, prepare standard reports, and provide the capability

to the user to develop some limited ad-hoc reports. The Excel emissions summary workbooks can

be found on the data disk in the directory semap/sm oke_emissions_summaries. There is one Excel

workbook for each SEMAP state.

6.1 OVERVIEW OF WORKSHEETS

The SMOKE emissions summary Excel files are macro-e nabled workbooks that contain the on-road

emissions estimates summaries from the SMOKE emissi ons reports from UNC. Each workbook

contains the following worksheets:

• State Summary Report Def - contains information us ed by an embedded Excel macro to

build the emissions estimates summary by state for the major vehicle classifications (State

Summary report)

• County Summary Report Def - contains information u sed by an embedded Excel macro to

build the emissions estimates summary by state and county for the major vehicle

classifications (State Summary report)

• Ozone Season Day Report Def - contains information used by an embedded Excel macro to

build the emissions estimates summary by state for the major vehicle classifications (State

Summary report)

• User Poll List - contains the list of pollutants t o include in each report

• SCC - contains a list of SCCs and their descriptio n

• AttLookUp - this is a scratch worksheet used by em bedded macros

• Month?? – monthly summary of the all the SMOKE rep orts that UNC provided where ?? is

month of the year (tons/month)

• State Summary - contains the annual emissions summ ary for the state (tons/year)

• State SCC Summary – contains the annual emissions summary for the state by SCC

(tons/year)

• County Summary - contains the annual emissions sum mary by state-county (tons/year)

• County SCC Summary – contains the annual emissions summary by state-county and SCC

(tons/year)

• Annual State Report Summary - contains the annual emissions estimates summary by major

vehicle category by state (tons/year)

• Annual County Report Summary - contains the annual emissions estimates summary by

major vehicle category by state and county (tons/ye ar)

• Ozone Season Day Summary - contains the emissions estimates summary for an average

ozone season day by major vehicle category by state (tons/day)

6.2 OVERVIEW OF EMBEDDED VBA MACROS

The workbook has the following embedded macros (pre ss Alt-F8) to see a list of these macros:

• CreateUserReportGroupByStateCounty - this macro cr eates a report based on user-defined

parameters. Example worksheets that contain the us er-defined parameters include:

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

24 AMEC 

# o State Summary Report Def;

o County Summary Report Def;

o Ozone Season Day Report Def

• DeleteSheet - a macro to delete a worksheet

• EmissionsByCounty - macro that creates the summari es contained in:

o County Summary;

o County SCC Summary

• EmissionsByState - macro that creates the summarie s contained in:

o State Summary;

o State SCC Summary

• ImportSMOKEReports - macro to import the SMOKE rep orts

If the user desires to rerun the reporting macros ( i.e., EmissionsByState, EmissionByCounty, or

CreateUserReportGroupByStateCounty), the workbook h as to have the macros enabled (which is

done when the user specifies such when the workbook is first opened). The user then needs to

press Alt-F8 to get a list of report macros to run, select the report macro, and press run.

For the report macro CreateUserReportGroupByStateCo unty, the system will ask for the name of the

worksheet (e.g., State Summary Report Def; County S ummary Report Def; Ozone Season Day

Report Def) that contains the information to genera te the user-defined report. The system will also

ask if the user wants to aggregate the pollutants. If the user responds “Yes," the system will use th e

chemical list from Column B of the User Poll List w orksheet. If the user responds "No," the system

will use the chemical list from Column A of the Use r Poll List worksheet.

For the report macros EmissionsByState and Emission sByCounty, The system will ask if the user

wants to aggregate the pollutants. If the user res ponds "Yes," the system will use the chemical list

from Column B of the User Poll List worksheet. If the user responds "No," the system will use the

chemical list from Column A of the User Poll List w orksheet.

6.3 USER POLL LIST WORKSHEET

The User Poll List worksheet has two columns. The chemicals in Column A name all the pollutants

that exist in the UNC data sets and the order that the chemicals are to be reported in the Month01

through Month12 worksheets. Column B lists the red uced set of "aggregated" chemicals and the

order that they are to appear in summary reports. The embedded macros use Column A or Column

B based on the user's response to whether to aggreg ate the chemicals (use Column B) or not to

aggregate the chemicals (use Column A).

The chemicals in Column B can be used to aggregate other values into a single value. In the current

worksheet, NO X



# is estimated as 1.533*NO + NO2. Another example h ow this aggregation can be

applied would be to make an entry in Column B for P M 10 

# as follows:

PM 10 

# =PMC+PMFINE

In order for this to appear in the reports, the use r would have to rerun the macros as discussed in

Section 6.2

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

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# 6.4 USER-DEFINED REPORTS

The worksheets -- State Summary Report Def; County Summary Report Def; and Ozone Season

Day Report Def -- contain information that is used by the embedded macro

"CreateUserReportGroupByStateCounty " to prepare em issions estimates summary reports. In

order to run the macro, certain cells need to be po pulated by the user as follows:

• C1 - name of the report (a worksheet is created wi th this name and can be no longer than 31

characters -- an Excel limitation).

• G1 - keyword STATE or COUNTY (STATE indicates that the macro will estimate the

emissions for the entire state; COUNTY indicates th at the macro will estimate the emissions

by state-county combination).

• C2, D2, E2, ..., N2 - the names of the Month?? wor ksheets to use in compiling the emissions

estimates report.

• C3 - units of the emissions estimates (e.g., tons/ day).

• C4 - emissions divisor (this divisor [d] is applie d to all emissions estimates [e] in the form of

[e] divided by [d]. for example, if you wanted an annual average day emissions estimate, in

Cells C2 through N2 you would list Month01, Month02 , ..., Month12 and in Cell C4 you would

enter 365.

• A5, B5, C5, ...., n - category names for the group ed SCCs.

• A6, A7, A8, ... n - for each category listed in A5 , B5, C5, and so on, the list B6, B7, B8, ... n

of SCCs that are to be included in the grouping. I f a “?” is specified in the SCC sequence, it

is treated as a wildcard thus matching any value in that position. For any SCC that is not

captured, the system will report these emissions es timates under the "Other" category and

will list these SCCs on the report definition works heet.

6.5 EXECUTION SPEED OF MACROS

The embedded macros do take time to run depending o n the complexity of the report that is being

generated. On a four-core Windows 7 machine, with each CPU operating at 2.4GHz, it takes

roughly sixty minutes each for the EmissionsByState and EmissionsByCounty macros to run to

completion. For the example user-defined reports i ncluded in the workbooks, the

CreateUserReportGroupByStateCounty macro takes anyw here from thirty minutes to seventy-five

minutes to run.

In each case, the status bar, which is located in t he lower left-hand corner of the Excel screen,

indicates the worksheet, state/county, SCC, and che mical that the macro is currently summarizing.

If at some point the user decides to run an embedde d macro and the status bar does not change

every five or ten seconds, it is highly likely that Excel has locked up and will need to be restarted.

Therefore, it is imperative that as the user comple tes each task with each workbook, that the

workbook be saved.

6.6 EMISSIONS ESTIMATES SUMMARIES

Summaries of the annual, SEMAP state-wide emissions estimates were prepared. Table 6-1 shows

the annual on-road mobile source emissions estimate s by state for the on-network and off-network

contributions by pollutant for gasoline fueled vehi cles. Table 6-2 shows the annual on-road mobile

source emissions estimates by state for the on-netw ork and off-network contributions by pollutant for

diesel fueled vehicles. Table 6-3 shows the annual on-road mobile source emissions estimates by

state for the on-network and off-network contributi ons by pollutant for gasoline and diesel fueled

vehicles. Table 6-4 shows the annual on-road mobil e source emissions estimates by state and

vehicle category. Table 6-5 shows the ozone season day on-road mobile source emissions

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

26 AMEC 

# estimates by state and vehicle category. Figure 6- 1 shows the percent contribution by state and fuel

to the annual on-road mobile source emissions estim ates.2007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201327AMECTable 6-1. Annual on-road mobile source emissionssummary by state and network from gasoline fueled vehicles (tons/year).StateNetworkCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTAL Off387,40725,61511,61933,44645,06552-327--327355--355On497,40171,5236,60319,43926,0421,1732,7037793821061,2668461,4584402,744State Total884,80797,13818,22252,88571,1061,2252,7031,1063821061,5931,2011,4584403,099FL Off809,84376,91141,59282,665124,257137-584--584634--634On1,694,406235,92124,61360,16484,7774,1579,3291,8731,3683233,5632,0345,2251,3478,606State Total2,504,249312,83266,205142,830209,0344,2959,3292,4571,3683234,1472,6685,2251,3479,240GA Off609,67151,13120,68859,61980,307177-665--665723--723On1,244,981173,15715,37353,53968,9125,5675,1441,7936091652,5661,9472,3256874,959State Total1,854,653224,28836,061113,158149,2205,7445,1442,4586091653,2322,6702,3256875,682KY Off340,58219,0737,52327,36734,89042-360--360391--391On345,20352,8194,18812,25416,4427582,075703209659777637982731,834State Total685,78571,89211,71139,62151,3328002,0751,062209651,3371,1547982732,225MS Off251,27916,1327,91320,60928,52232-203--203221--221On255,22338,7883,2938,77712,0706511,703394161556104286142301,273State Total506,50354,92011,20629,38540,5926831,703598161558146496142301,494NC Off904,37839,80924,16058,03782,19794-743--743807--807On1,174,460144,4969,68135,87445,5552,0984,8791,9823721342,4882,1521,4205604,132State Total2,078,838184,30533,84093,912127,7522,1924,8792,7253721343,2312,9591,4205604,939SC Off296,25018,7358,55222,73231,28342-221--221240--240On427,81756,3054,45013,51917,9699992,189585248719046359472941,877State Total724,06775,04113,00136,25149,2521,0412,189806248711,1248759472942,116TN Off518,44828,71117,46636,79654,26266-450--450489--489On646,53487,7015,78019,63025,4101,2903,0961,012211771,3001,0998073212,227State Total1,164,983116,41223,24656,42679,6711,3563,0961,462211771,7501,5888073212,716VA Off643,62933,50115,38851,01166,39964-708--708769--769On522,60176,0847,91717,13725,0541,0303,8841,3282441041,6761,4429334342,809State Total1,166,230109,58523,30568,14891,4531,0933,8842,0362441042,3842,2119334343,578WV Off181,7568,3793,39912,39215,79122-174--174189--189On166,96022,4641,6045,1956,8003718333288226436356313109779State Total348,71630,8435,00417,58722,5913938335038226611546313109968SEMAP Off4,943,243317,997158,299404,674562,973728-4,436--4,4364,817--4,817On6,975,587959,25983,502245,528329,03018,09435,83610,7763,8851,12615,78711,70314,8424,69531,240Total11,918,8301,277,256241,801650,202892,00318,82235,83615,2123,8851,12620,22316,52014,8424,69536,0572007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201328AMECTable 6-2. Annual on-road mobile source emissionssummary by state and network from diesel fueled vehicles (tons/year).StateNetworkCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTALOff 5,44810,117-2,3202,320120190--190196--196On 19,19565,412-3,6523,6522721203,98696224,1044,109367904,566State Total 24,64375,530-5,9715,9712841204,17696224,2944,305367904,762FLOff 12,01520,460-4,8944,894280496--496511--511On 49,187165,643-8,9688,9688293479,490291569,8379,7831,11223411,130State Total 61,202186,103-13,86313,8638573479,9862915610,33310,2941,11223411,641GAOff 7,53013,051-3,0093,009160250--250258--258On 47,208159,498-8,6868,6866472719,9122394810,19910,21891220211,332State Total 54,738172,549-11,69411,69466327110,1622394810,44910,47691220211,590KYOff 4,6679,086-2,0382,038100157--157162--162On 13,55952,447-2,5132,513211972,80649142,8682,892186583,137State Total 18,22661,533-4,5514,551222972,96349143,0263,055186583,299MSOff 4,3808,054-1,8481,848100170--170175--175On 14,49354,251-2,6672,6672271063,01250153,0783,106192633,361State Total 18,87362,305-4,5144,5142371063,18250153,2483,280192633,536NCOff 12,24424,555-5,5685,568280444--444458--458On 19,89071,809-3,7443,7443141743,63947203,7063,751181814,014State Total 32,13496,364-9,3129,3123421744,08347204,1504,209181814,472SCOff 3,5996,724-1,5421,54280122--122126--126On 17,80962,715-3,2293,2292641143,64089183,7483,753341774,171State Total 21,40869,439-4,7714,7712721143,76389183,8703,879341774,297TNOff 4,9649,482-2,1472,147110170--170175--175On 27,718122,910-4,9954,9954902265,77757275,8615,9562181126,285State Total 32,682132,392-7,1427,1425012265,94757276,0316,1312181126,461VAOff 3,1885,333-1,2011,20170122--122126--126On 19,49381,825-3,6443,6443291573,93055214,0064,051210864,348State Total 22,68187,159-4,8454,8453351574,05255214,1284,177210864,473WVOff 3,3087,168-1,5621,56280116--116120--120On 5,55821,957-1,0521,05287421,1741961,1991,21074241,308State Total 8,86529,125-2,6142,61495421,2901961,3151,33074241,428SEMAPOff 61,342114,033-26,12926,12913802,238--2,2382,307--2,307On 234,110858,467-43,14843,1483,6701,65447,36699324648,60648,8293,7941,02853,651Total 295,453972,499-69,27769,2773,8081,65449,60499324650,84451,1373,7941,02855,9592007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201329AMECTable 6-3. Annual on-road mobile source emissionssummary by state and network from gasoline and diesel fueled vehicles (tons/year).StateNetworkCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTALOff 392,85535,73211,61935,76547,384640517--517551--551On 516,595136,9356,60323,09029,6941,4452,8234,7654781275,3704,9551,8255307,310State Total909,450172,66818,22258,85677,0781,5092,8235,2824781275,8875,5061,8255307,861FLOff 821,85797,37141,59287,559129,15116501,080--1,0801,146--1,146On 1,743,593401,56524,61369,13393,7464,9879,67611,3621,65937913,40011,8166,3371,58219,735State Total2,565,451498,93566,205156,692222,8975,1519,67612,4421,65937914,48012,9626,3371,58220,881GAOff 617,20264,18320,68862,62883,3161930915--915980--980On 1,292,189332,65515,37362,22577,5986,2145,41611,70584821312,76512,1653,23888816,291State Total1,909,391396,83736,061124,853160,9146,4075,41612,62084821313,68113,1453,23888817,271KYOff 345,24928,1607,52329,40536,928530517--517553--553On 358,762105,2664,18814,76718,9559692,1723,508258793,8453,6569853314,971State Total704,011133,42511,71144,17255,8831,0222,1724,026258794,3634,2099853315,524MSOff 255,65924,1867,91322,45630,369420373--373396--396On 269,71693,0393,29311,44314,7378771,8093,407211703,6883,5348072944,634State Total525,375117,22511,20633,89945,1069201,8093,780211704,0613,9298072945,030NCOff 916,62264,36424,16063,60687,76612201,187--1,1871,265--1,265On 1,194,351216,3059,68139,61849,2992,4125,0535,6214191546,1945,9031,6016418,146State Total2,110,972280,67033,840103,224137,0642,5345,0536,8084191547,3817,1681,6016419,411SCOff 299,84925,4608,55224,27432,826500343--343366--366On 445,626119,0204,45016,74821,1981,2632,3034,225337894,6524,3881,2883716,047State Total745,475144,48013,00141,02254,0231,3132,3034,568337894,9944,7541,2883716,413TNOff 523,41238,19317,46638,94356,409770621--621664--664On 674,253210,6115,78024,62430,4041,7803,3226,7892681047,1617,0541,0254338,512State Total1,197,665248,80423,24663,56786,8131,8573,3227,4092681047,7817,7191,0254339,177VAOff 646,81638,83515,38852,21267,600700830--830894--894On 542,095157,9097,91720,78128,6981,3584,0415,2582991255,6825,4941,1435207,157State Total1,188,911196,74423,30572,99296,2971,4294,0416,0882991256,5126,3881,1435208,051WVOff 185,06415,5473,39913,95517,354300291--291309--309On 172,51744,4211,6046,2477,8524588751,502101321,6351,5663871332,087State Total357,58159,9685,00420,20225,2054878751,793101321,9261,8763871332,397SEMAPOff 5,004,586432,030158,299430,803589,10286606,674--6,6747,124--7,124On 7,209,6971,817,72583,502288,677372,17921,76337,49058,1424,8791,37264,39360,53218,6365,72384,892Total 12,214,2832,249,755241,801719,480961,28122,62937,49064,8164,8791,37271,06767,65718,6365,72392,0162007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201330AMECTable 6-4. Annual on-road mobile source emissionssummary by state and vehicle category (tons/year).StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTALLDGV 308,55639,9898,52618,58327,1096021,621471167606985126392491,399LDGT1 344,59934,8315,31121,18426,494377686397121275464324631131,008LDGT2 118,35411,9651,8257,2789,10213023613742918814815939346HDGV 106,23110,0941,3155,3626,677111149905291509719738333MC 7,0682591,2454791,724511110011120113LDDV2480-771060076107LDDT328486-656522311031312135HDDV 24,14874,730-5,8855,8852811184,12695214,2424,254362894,705BUSES143234-151510130014141016State Total909,450172,66818,22258,85677,0781,5092,8235,2824781275,8875,5061,8255307,861FLLDGV 1,165,545155,63440,23064,227104,4572,2695,9441,3656691952,2291,4822,5558144,851LDGT1 866,109104,41913,77750,20363,9791,3732,325724477871,2877861,8203642,970LDGT2 349,72740,2526,15222,12328,274478799278164304723026251251,052HDGV 102,62011,8651,1674,9176,0841612356758101357322342337MC 20,2486624,8801,3606,2401326230124251329LDDV239482-666621831084863189LDDT1,8852,716-3363369615531158160102172HDDV 57,365176,595-13,21313,2138243319,377277549,7089,6671,05922310,949BUSES 1,7136,311-247247219370112383382418431State Total2,565,451498,93566,205156,692222,8975,1519,67612,4421,65937914,48012,9626,3371,58220,881GALDGV 588,53769,13915,80739,76055,5682,1212,267967191711,2291,0507312952,076LDGT1 767,53995,06411,66745,33957,0052,1921,763914247561,2179939432342,170LDGT2 365,56446,0995,34620,92526,2711,082884440123285914784691171,064HDGV 117,80513,3911,4406,0667,50532821711748917412818239348MC 15,2085951,8021,0692,8712214190020211224LDDV41115-131310160016161018LDDT1,0391,439-204204661002110210372112HDDV 51,873166,257-11,18111,1816422589,7602284610,03510,06287219211,126BUSES 1,7864,738-29729714728682296295327334State Total1,909,391396,83736,061124,853160,9146,4075,41612,62084821313,68113,1453,23888817,271KYLDGV 253,05429,5505,79915,64921,4483891,21846095375924993631561,018LDGT1 271,65627,4173,40615,87319,279263577392761948642628977792LDGT2 79,7017,6209704,4605,430801571101851331206921210HDGV 75,8897,1127713,3464,11665116922041171007719196MC 5,4851937642941,058389009100110LDDV1547-550040044005LDDT178272-393911180018181020HDDV 17,91260,986-4,4944,494220952,92948142,9913,020184573,260BUSES121228-141410120013131014State Total704,011133,42511,71144,17255,8831,0222,1724,026258794,3634,2099853315,5242007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201331AMECTable 6-4. (continued)StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTMSLDGV 213,45328,6595,49111,94117,4324381,24930710140448334385166885LDGT1 222,00421,0073,52213,82517,348200378228491329024818853488LDGT2 14,5721,3792319081,13913251531191612332HDGV 53,1653,7557792,5173,29530464382534729884MC 3,3091201,1831951,3782540045005LDDV113389-323232281029293134LDDT564831-11411444531055553160HDDV 17,63659,216-4,2784,278224983,00047143,0603,092178583,329BUSES5591,870-9191631012110310482114State Total525,375117,22511,20633,89945,1069201,8093,780211704,0613,9298072945,030NCLDGV 533,16347,51713,08426,81339,8967451,995748113569168124322321,476LDGT1 1,022,22787,75513,34145,83559,1759091,8431,258161491,4681,3666152062,186LDGT2 352,58730,8774,50815,60620,115324659440581851647822074772HDGV 144,28417,3768854,5245,409200353250401130127215347471MC 26,5777812,0221,1343,1571328290030321234LDDV134315-545421550055561158LDDT8681,268-178178679310949652102HDDV 30,44393,628-9,0109,0103311653,88045193,9444,000172784,250BUSES6881,153-696942561057573162State Total2,110,972280,67033,840103,224137,0642,5345,0536,8084191547,3817,1681,6016419,411SCLDGV 260,09129,2666,62113,63420,2544411,1693479535478377364148889LDGT1 287,91329,4173,52714,47017,997388667291992341331737795789LDGT2 106,94311,1631,2765,2466,52215126011139915812014737304HDGV 59,9434,9056642,4363,10156814515364495813121MC 9,1772909144651,379613110011120113LDDV1964-551050055106LDDT336508-666622311032322135HDDV 20,46766,849-4,6004,6002631093,60785183,7103,719326734,118BUSES5862,018-1001006312031124124122138State Total745,475144,48013,00141,02254,0231,3132,3034,568337894,9944,7541,2883716,413TNLDGV 394,56738,20912,19222,68834,8804811,3315496632647597251135983LDGT1 494,33452,1666,33522,15128,4865901,20960198307296523761261,154LDGT2 169,33017,8532,1737,5959,769202413206341025022412843395HDGV 93,5387,7681,1133,4434,5567612691144108985215165MC 13,2134161,4325481,981716150016170118LDDV91338-242432241025242128LDDT2237-880-2--22--2HDDV 32,040130,331-7,0287,0284932225,83455265,9156,0142091096,332BUSES5291,685-838352882090916299State Total1,197,665248,80423,24663,56786,8131,8573,3227,4092681047,7817,7191,0254339,1772007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201332AMECTable 6-4. (concluded)StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTVALDGV 598,03166,89413,93132,69846,6298163,2581,332185861,6041,4477083592,515LDGT1 327,31424,7604,69320,92025,613159368406331044944112743610LDGT2 168,61412,7572,41810,77713,194821892101752322286522315HDGV 62,7874,8567153,2333,948335874928480339121MC 9,4853181,5485202,068411140015160117LDDV86264-292921310031322134LDDT562879-13513544551056572160HDDV 19,97379,351-4,3494,3493091423,61447183,6803,726179773,982BUSES 2,0606,664-332332201035272361363277397State Total1,188,911196,74423,30572,99296,2971,4294,0416,0882991256,5126,3881,1435208,051WVLDGV 103,22710,2801,9075,3377,244160424168311321218311954356LDGT1 183,90614,6072,0639,63011,69315827924235928726313438435LDGT2 43,8244,1734462,0552,50152956512380714613129HDGV 13,1121,6475735941620302141252214441MC 4,6481365302077372560077008LDDV2358-11110070078008LDDT115180-252511120012131014HDDV8,47428,126-2,5392,53991401,2311851,2551,26970231,362BUSES252761-393921391040413144State Total357,58159,9685,00420,20225,2054878751,793101321,9261,8763871332,397SEMAPLDGV 4,418,223515,137123,588251,328374,9178,46220,4756,7141,7146259,0537,2926,5462,60816,446LDGT1 4,787,601491,44467,641259,430327,0706,60910,0955,4531,3963237,1725,9225,3321,34812,602LDGT2 1,769,215184,13725,34596,972122,3172,5933,7172,0125081182,6392,1851,9424944,621HDGV 829,37582,7688,90736,20145,1081,0801,412890266561,2129661,0182332,217MC 114,4163,77116,3206,27122,5927713614313147155512172LDDV7852,153-24524515825841263266146286LDDT5,8978,615-1,1691,1693632549935605663511611HDDV 280,332936,069-66,57666,5763,6771,57847,35994523548,53948,8223,61198053,414BUSES 8,43925,662-1,2871,28780361,4383571,4801,482134311,648Total 12,214,2832,249,755241,801719,480961,28122,62937,49064,8164,8791,37271,06767,65718,6365,72392,0162007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201333AMECTable 6-5. Ozone season day on-road mobile sourceemissions summary by state and vehicle category (tons/day).StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTALLDGV810.0112.925.246.571.71.74.61.00.50.21.71.11.80.73.6LDGT1915.897.515.955.070.91.12.00.80.30.11.30.91.30.32.5LDGT2313.833.45.518.924.30.40.70.30.10.00.40.30.40.10.9HDGV276.626.73.814.017.80.30.40.20.10.00.30.20.50.10.8MC 17.50.63.71.35.00.00.00.00.00.00.00.00.00.00.0LDDV0.10.2-0.00.00.00.00.00.00.00.00.00.00.00.0LDDT1.01.4-0.20.20.00.00.10.00.00.10.10.00.00.1HDDV67.1193.6-15.915.90.80.311.30.30.111.611.61.00.212.9BUSES0.40.6-0.00.00.00.00.00.00.00.00.00.00.00.0State Total2,402.2466.854.2151.8206.04.38.013.81.30.415.514.35.11.520.9FLLDGV 3,244.6441.6108.2176.6284.96.616.83.51.90.66.03.87.22.313.3LDGT1 2,398.5296.037.2139.0176.14.06.61.91.30.23.52.05.21.08.2LDGT2946.0112.716.560.677.01.42.20.70.50.11.20.81.70.42.9HDGV274.732.13.113.416.60.50.60.20.20.00.40.20.60.10.9MC 50.51.712.63.716.30.00.10.10.00.00.10.10.00.00.1LDDV0.71.3-0.10.10.00.00.20.00.00.20.20.00.00.2LDDT5.47.4-0.80.80.00.00.40.00.00.40.40.00.00.5HDDV159.6467.1-36.236.22.30.925.70.80.126.626.52.90.630.0BUSES4.716.6-0.70.70.10.01.00.00.01.01.00.10.01.2State Total7,084.81,376.5177.6431.0608.614.827.333.64.61.139.435.017.84.457.2GALDGV 1,742.2221.944.7106.4151.010.66.52.10.50.22.82.22.10.85.2LDGT1 2,416.8293.233.1133.0166.211.05.02.00.70.22.92.22.70.75.5LDGT2 1,162.4141.815.162.077.15.42.51.00.30.11.41.01.30.32.7HDGV361.839.84.018.021.91.60.60.20.10.00.40.30.50.10.9MC 48.72.05.03.58.50.10.00.00.00.00.00.00.00.00.1LDDV0.10.3-0.00.00.00.00.00.00.00.00.00.00.00.0LDDT3.14.0-0.60.60.00.00.30.00.00.30.30.00.00.3HDDV144.2431.2-30.430.41.80.726.70.60.127.527.52.40.530.4BUSES4.912.2-0.80.80.00.00.80.00.00.80.80.10.00.9State Total5,884.21,146.5101.9354.6456.530.615.433.12.40.636.134.49.12.546.0KYLDGV585.481.017.635.753.31.13.50.80.30.11.20.91.00.42.4LDGT1668.475.410.439.850.20.71.70.70.20.11.00.70.80.21.8LDGT2193.621.03.011.214.10.20.40.20.10.00.30.20.20.10.5HDGV185.718.52.38.510.80.20.30.20.10.00.20.20.20.10.4MC 12.30.52.40.83.20.00.00.00.00.00.00.00.00.00.0LDDV0.00.1-0.00.00.00.00.00.00.00.00.00.00.00.0LDDT0.50.7-0.10.10.00.00.00.00.00.00.00.00.00.1HDDV49.4157.5-12.112.10.60.38.00.10.08.28.30.50.28.9BUSES0.30.6-0.00.00.00.00.00.00.00.00.00.00.00.0State Total1,695.6355.335.6108.1143.82.96.210.00.70.210.910.42.80.914.12007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201334AMECTable 6-5. (continued)StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTMSLDGV569.780.816.230.746.91.33.60.70.30.11.10.71.10.52.3LDGT1575.358.110.636.046.60.61.10.50.10.00.60.50.50.11.2LDGT237.73.80.72.43.10.00.10.00.00.00.00.00.00.00.1HDGV134.39.92.36.58.80.10.10.10.00.00.10.10.10.00.2MC 7.90.33.60.54.10.00.00.00.00.00.00.00.00.00.0LDDV0.31.1-0.10.10.00.00.10.00.00.10.10.00.00.1LDDT1.72.3-0.30.30.00.00.10.00.00.10.20.00.00.2HDDV48.9152.6-11.511.50.60.38.20.10.08.48.50.50.29.1BUSES1.54.8-0.20.20.00.00.30.00.00.30.30.00.00.3State Total1,377.3313.633.388.2121.52.65.210.00.60.210.810.42.30.813.5NCLDGV 1,156.5128.834.763.498.12.25.71.50.30.22.01.61.20.73.5LDGT1 2,459.1238.635.6118.8154.32.65.32.50.50.13.12.81.70.65.1LDGT2851.483.812.040.652.60.91.90.90.20.11.11.00.60.21.8HDGV359.244.82.412.414.80.61.00.50.10.00.60.50.40.11.1MC 56.01.95.13.08.20.00.10.10.00.00.10.10.00.00.1LDDV0.30.8-0.10.10.00.00.10.00.00.20.20.00.00.2LDDT2.63.5-0.50.50.00.00.30.00.00.30.30.00.00.3HDDV84.8241.2-24.524.50.90.510.60.10.110.810.90.50.211.6BUSES1.92.9-0.20.20.00.00.20.00.00.20.20.00.00.2State Total4,971.8746.489.9263.3353.27.314.416.71.20.418.317.54.51.823.8SCLDGV643.580.618.234.452.71.33.30.70.30.11.10.81.00.42.3LDGT1739.081.49.738.248.01.11.90.60.30.11.00.71.10.32.0LDGT2275.230.83.513.917.40.40.70.20.10.00.40.30.40.10.8HDGV147.012.81.86.38.10.20.20.10.00.00.10.10.20.00.3MC 21.00.72.41.33.70.00.00.00.00.00.00.00.00.00.0LDDV0.10.2-0.00.00.00.00.00.00.00.00.00.00.00.0LDDT1.01.4-0.20.20.00.00.10.00.00.10.10.00.00.1HDDV56.8172.8-12.512.50.70.39.90.20.010.210.20.90.211.3BUSES1.65.2-0.30.30.00.00.30.00.00.30.30.00.00.4State Total1,885.1385.935.7107.1142.83.86.512.00.90.313.212.53.61.017.1TNLDGV820.5102.533.452.385.71.43.81.00.20.11.31.10.70.42.2LDGT1 1,210.5142.217.557.875.41.73.51.20.30.11.51.31.10.42.7LDGT2412.648.46.019.825.80.61.20.40.10.00.50.40.40.10.9HDGV214.520.13.08.711.80.20.30.20.00.00.20.20.10.00.4MC 27.51.03.91.55.40.00.00.00.00.00.00.00.00.00.0LDDV0.30.9-0.10.10.00.00.10.00.00.10.10.00.00.1LDDT0.10.1-0.00.00.0-0.0--0.00.0--0.0HDDV88.5337.7-19.019.01.40.616.00.10.116.216.50.60.317.3BUSES1.44.4-0.20.20.00.00.20.00.00.20.20.00.00.3State Total2,775.8657.263.8159.5223.35.39.419.10.80.320.119.82.91.223.92007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201335AMECTable 6-4. (concluded)StateCategoryCONOXVOC-EVPVOC-EXHVOC-TOTSO2NH3PM25EXHPM25BRAKEPM25TIREPM25-TOTPM10EXHPM10BRAKEPM10TIREPM10-TOTVALDGV 1,442.5 182.3 39.9 77.7 117.6 2.4 9.3 2.5 0.50.2 3.3 2.7 2.0 1.0 5.8LDGT1 737.3 66.4 13.5 50.3 63.8 0.5 1.1 0.7 0.1 0.00.8 0.8 0.4 0.1 1.2LDGT2 379.1 34.1 7.0 25.9 32.8 0.2 0.5 0.4 0.0 0.00.4 0.4 0.2 0.1 0.6HDGV 142.7 12.5 2.0 7.8 9.9 0.1 0.2 0.1 0.0 0.0 0.20.1 0.1 0.0 0.2MC 20.6 0.8 4.3 1.3 5.6 0.0 0.0 0.0 0.0 0.0 0.0 0.00.0 0.0 0.0LDDV 0.2 0.7 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 0.10.0 0.0 0.1LDDT 1.6 2.3 - 0.3 0.3 0.0 0.0 0.2 0.0 0.0 0.2 0.20.0 0.0 0.2HDDV 54.8 205.9 - 11.7 11.7 0.9 0.4 9.9 0.1 0.1 10.1 10.2 0.5 0.2 10.9BUSES 5.6 17.3 - 0.9 0.9 0.1 0.0 1.0 0.0 0.0 1.0 1.0 0.1 0.0 1.1State Total2,784.4 522.4 66.7 175.9 242.6 4.1 11.5 14.8 0.8 0.4 16.0 15.5 3.2 1.5 20.2WVLDGV 212.8 27.7 5.5 11.7 17.2 0.5 1.2 0.3 0.1 0.0 0.4 0.3 0.3 0.2 0.8LDGT1 401.0 39.4 6.0 23.1 29.1 0.5 0.8 0.4 0.1 0.00.5 0.4 0.4 0.1 0.9LDGT2 100.5 11.3 1.3 5.1 6.4 0.1 0.3 0.1 0.0 0.0 0.2 0.1 0.1 0.0 0.3HDGV 31.2 4.2 0.2 1.0 1.1 0.1 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1MC 9.4 0.3 1.5 0.5 2.1 0.0 0.0 0.0 0.0 0.0 0.0 0.00.0 0.0 0.0LDDV 0.1 0.1 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.00.0 0.0 0.0LDDT 0.3 0.5 - 0.1 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.00.0 0.0 0.0HDDV 23.3 72.8 - 6.9 6.9 0.3 0.1 3.4 0.1 0.0 3.4 3.5 0.2 0.1 3.7BUSES 0.7 2.0 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 0.10.0 0.0 0.1State Total779.3 158.3 14.5 48.5 63.0 1.4 2.5 4.4 0.3 0.1 4.84.6 1.1 0.4 6.0SEMAPLDGV 11,227.7 1,460.0 343.6 635.4 979.0 29.0 58.3 14.1 4.9 1.8 20.8 15.4 18.5 7.4 41.3LDGT1 12,521.8 1,388.2 189.5 691.1 880.6 23.7 28.811.3 4.0 0.9 16.2 12.3 15.1 3.8 31.2LDGT2 4,672.2 521.1 70.5 260.2 330.7 9.8 10.6 4.2 1.4 0.3 5.9 4.5 5.5 1.4 11.4HDGV 2,127.7 221.4 25.0 96.6 121.6 3.7 3.9 1.8 0.70.2 2.6 1.9 2.8 0.6 5.3MC 271.3 10.0 44.6 17.4 61.9 0.3 0.4 0.3 0.0 0.0 0.3 0.3 0.0 0.0 0.4LDDV 2.2 5.7 - 0.5 0.5 0.0 0.0 0.7 0.0 0.0 0.7 0.70.0 0.0 0.8LDDT 17.4 23.7 - 3.0 3.0 0.1 0.1 1.5 0.0 0.0 1.5 1.5 0.1 0.0 1.7HDDV 777.2 2,432.3 - 180.5 180.5 10.3 4.3 129.6 2.60.6 132.8 133.6 9.9 2.7 146.2BUSES 23.0 66.5 - 3.4 3.4 0.2 0.1 3.9 0.1 0.0 4.1 4.1 0.4 0.1 4.5Total 31,640.4 6,128.9 673.2 1,888.1 2,561.3 77.1 106.4 167.5 13.7 3.9 185.0 174.4 52.3 16.1 242.82007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201336AMECFigure 6-1. Percentage contribution by state and fuel to annual on-road mobile source emissions estimates.AL Diesel, 24,643 , 0%AL Gasoline,884,807 , 7%FL Diesel, 61,202 , 1%FL Gasoline, 2,504,249 ,21%GA Diesel, 54,738 , 0%GA Gasoline, 1,854,653 ,15%KY Diesel, 18,226 , 0%KY Gasoline,685,785 , 6%MS Diesel, 18,873 , 0%MS Gasoline,506,503 , 4%NC Diesel, 32,134 , 0%NC Gasoline, 2,078,838 ,17%SC Diesel, 21,408 , 0%SC Gasoline, 724,067 ,6%TN Diesel, 32,682 , 0%TN Gasoline, 1,164,983 ,10%VA Diesel, 22,681 , 0%VA Gasoline,1,166,230 , 10%WV Diesel, 8,865 , 0%WV Gasoline,348,716 , 3%**CO**AL Diesel, 75,530 , 3%AL Gasoline, 97,138 , 4%FL Diesel,186,103 , 8%FL Gasoline, 312,832 ,14%GA Diesel, 172,549 ,8%GA Gasoline,224,288 , 10%KY Diesel, 61,533 , 3%KY Gasoline, 71,892 , 3%MS Diesel, 62,305 , 3%MS Gasoline, 54,920 , 2%NC Diesel, 96,364 , 4%NC Gasoline, 184,305 ,8%SC Diesel, 69,439 , 3%SC Gasoline, 75,041 , 3%TN Diesel,132,392 , 6%TN Gasoline, 116,412 ,5%VA Diesel, 87,159 , 4%VA Gasoline,109,585 , 5%WV Diesel,29,125 , 1%WV Gasoline, 30,843 ,1%**NOX**AL Diesel, 5,971 , 1%AL Gasoline,71,106 , 7%FL Diesel, 13,863 , 1%FL Gasoline, 209,034 ,22%GA Diesel, 11,694 , 1%GA Gasoline, 149,220 ,16%KY Diesel, 4,551 , 0%KY Gasoline, 51,332 , 5%MS Diesel,4,514 , 0%MS Gasoline, 40,592 , 4%NC Diesel, 9,312 , 1%NC Gasoline, 127,752 ,13%SC Diesel, 4,771 , 0%SC Gasoline, 49,252 , 5%TN Diesel, 7,142 , 1%TN Gasoline, 79,671, 8%VA Diesel, 4,845 , 1%VA Gasoline,91,453 , 10%WV Diesel, 2,614 , 0%WV Gasoline, 22,591 ,2%**VOC -** **TOT**AL Diesel, 284 , 1%AL Gasoline, 1,225 , 5%FL Diesel, 857 , 4%FL Gasoline, 4,295 , 19%GA Diesel, 663 , 3%GA Gasoline, 5,744 , 25%KY Diesel, 222 , 1%KY Gasoline, 800 , 4%MS Diesel, 237 , 1%MS Gasoline, 683 , 3%NC Diesel, 342 , 2%NC Gasoline, 2,192 , 10%SC Diesel, 272 , 1%SC Gasoline, 1,041 , 5%TN Diesel, 501 , 2%TNGasoline,1,356 , 6%VA Diesel, 335 , 1%VA Gasoline, 1,093 , 5%WV Diesel, 95 , 0%WV Gasoline,393 , 2%**SO2**AL Diesel, 120 , 0%AL Gasoline,2,703 , 7%FL Diesel, 347 , 1%FL Gasoline, 9,329 , 25%GA Diesel, 271 , 1%GA Gasoline, 5,144 , 14%KY Diesel, 97 , 0%KYGasoline,2,075 , 6%MS Diesel,106 , 0%MS Gasoline, 1,703 , 5%NC Diesel, 174 , 0%NC Gasoline, 4,879 , 13%SC Diesel, 114 , 0%SC Gasoline, 2,189 , 6%TN Diesel, 226 , 1%TN Gasoline, 3,096 ,8%VA Diesel, 157 , 0%VA Gasoline, 3,884 ,10%WV Diesel, 42 , 0%WV Gasoline, 833 , 2%**NH3**AL Diesel,4,294 , 6%AL Gasoline, 1,593 , 2%FL Diesel, 10,333 , 15%FL Gasoline, 4,147 , 6%GA Diesel, 10,449 , 15%GA Gasoline, 3,232 , 5%KY Diesel,3,026 , 4%KY Gasoline, 1,337 , 2%MS Diesel, 3,248 , 5%MS Gasoline, 814 , 1%NC Diesel,4,150 , 6%NC Gasoline, 3,231 , 5%SC Diesel, 3,870 , 5%SC Gasoline, 1,124 , 2%TN Diesel, 6,031 , 8%TN Gasoline, 1,750 , 2%VA Diesel,4,128 , 6%VA Gasoline, 2,384 , 3%WV Diesel, 1,315 , 2%WV Gasoline, 611 , 1%**PM25-TOT**AL Diesel,4,762 , 5%AL Gasoline, 3,099 , 3%FL Diesel, 11,641 , 13%FL Gasoline, 9,240 , 10%GA Diesel, 11,590 , 13%GAGasoline,5,682 , 6%KY Diesel, 3,299 , 4%KY Gasoline, 2,225 , 2%MS Diesel, 3,536 , 4%MS Gasoline, 1,494 , 2%NC Diesel, 4,472 , 5%NC Gasoline,4,939 , 5%SC Diesel, 4,297 , 5%SC Gasoline, 2,116 , 2%TN Diesel, 6,461 , 7%TN Gasoline, 2,716 , 3%VA Diesel, 4,473 , 5%VA Gasoline, 3,578 , 4%WV Diesel,1,428 , 2%WV Gasoline, 968 , 1%**PM10-TOT**

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

37 AMEC 

# 7.0 DATA DISK

A data disk containing an archive of the informatio n developed during the study was prepared. The

contents of the archive are described in Table 7-1.2007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201338AMECTable 7-1. Description of data disk archive for the SEMAP 2007 MOVES2010a study.semap(directory)||-- 2007_MOVES_MySQL_inputsMySQL input data base archives of MOVES2010a runs||-- 2007_MOVES_MySQL_outputsMySQL output data base archives of MOVES2010a runs||-- edss(directory) SMOKE files files for use withMET4MOVES| || |-- data_semap(directory)| | || | |-- ge_data(directory)| | | || | | |-- fuelmonth_semap_??.txtFuel month cross-reference file for use inMET4MOVES and MOVES2010a| | | || | | |-- mcref_semap_??_2007.txtRepresentative county cross-reference filefor use in MET4MOVES and MOVES2010a| | | || | | |-- GRDDESCStandard SMOKE grid definition file used by MET4MOVEs| | | || | | |-- SRGDESC.MOVES.NCStandard SMOKE spatial surrogates definition file used by MET4MOVES| | | || | | |-- Srg_12km_MOVES_SEMAP(directory) containing standard SMOKE spatial surrogates used by MET4MOVES| | | || | | |-- metlist.met4moves.lstFile containing list of netCDF MCIP filesfor use by MET4MOVES| | || | |-- inventory(directory)| | | || | | |-- MOVES_2007(directory)| | | | || | | | |-- mobile(directory) files for use by UNC in SMOKEmodeling| | | | || | | | |-- onroad_dat(directory) files for use by UNC in SMOKEmodeling| | || | |-- met(directory) containing netCDF MCIP files for MET4MOVES (referenced by| | |metlist.met4moves.lst)| | |-- met_out(directory)| | | || | | |-- 12k(directory) containing output from MET4MOVES (SMOKE and MOVES compatible met| | |data sets)| | |-- run_MOVES_2007(directory)| | | || | | |-- static(directory)| | | | || | | | |-- logs(directory) containing diagnostic log files output by MET4MOVES| || |-- subsys(directory)| | || | |-- smoke(directory)| | | || | | |-- assigns_semap(directory)| | | | || | | | |-- ASSIGNS.MOVES.cmaq.cb05p25tx.semap.12k SMOKE ASSIGNS file used by MET4MOVES| | | || | | |-- scripts(directory)2007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201339AMEC| | | | || | | | |-- run_met4moves.MOVES.semap.??.bat C-shell scripts to run MET4MOVES||-- moves2smoke_windows(directory) containing MOVES2010a emissions factors archives delivered to UNC.|Also contains Windows-based scripts to extract MOVES2010a emissions|factors from MySQL output database archnives.||-- moves2moke_linux(directory) containing example scripts andresults from running emissions factor|extraction procedures on a linux platform (still in testing mode).||-- moves_emissions_factors_qa(directory) containing example Excel workbooks with VBA macros to ingest|MOVES2010a emissions factors and develop consolidated graphics for|QA purposes.||-- rh_rvp_sensitivity_experiments(directory) containing Consolidated Excelworkbooks summarizing RH and RVP|MOVES2010a sensitivity experiments.||-- smoke_moves_input(directory) containing the MOVES2010a datainputs developed during the study.| || |-- ??(directories) one directory per state| | || | |-- SSCCC_FuelFormulation.csvMOVES2010a fuel formulation input file| | || | |-- SSCCC_FuelSupply.csvMOVES2010a fuel supply input file| | || | |-- SSCCC_HPMSVTypeVMT.csvMOVES2010a annual VMT input file| | || | |-- SSCCC_IMCoverage.csvMOVES2010a I/M input file| | || | |-- SSCCC_sourceTypeAgeDistribution.csvMOVES2010a mode year age distribution input file| | || | |-- SSCCC_sourceTypePopulatin.csvMOVES2010a vehicle population count inputfile| | || | |-- MOVES_12km_2007001-2007365_??.txtMOVES2010a meteorological input file (replicated from met_out/12k)| | || | |-- SMOKE_12km_2007001-2007365_??.txtSMOKE meteorological input file (replicated from met_out/12k)||-- smoke_moves_input_qa(directory) MOVES2010a input QA results| || |-- ??(directories) one directory per state||-- smoke_moves_output(directory) containing SMOKE-MOVES Integration Tool Run Specification Generator| |results| || |-- ??(directories) one directory per state| | || | |-- dummy*csvStandard SMOKE-MOVES Integration Tool files| | || | |-- *imp.xmlMOVES2010a XML data import scripts from SMOKE-MOVES Integration Tool| | |Run Specification Generator| | || | |-- *mrs.xmlMOVES2010a XML run specification scripts from SMOKE-MOVES Integration| | |Tool Run Specification Generator| | || | |-- *.csvMOVES2010a compatible meteorological filefrom SMOKE-MOVES Integration2007 MOVES2010a On-road Mobile Source Emissions Factors for theSoutheastern Modeling Analysis and Planning (SEMAP)StatesMarch 21, 201340AMEC| | |Tool Run Specification Generator| | || | |-- jobs(directory)| | | || | | |-- SEMAP_??_2007importer.cshMOVES2010a C-shell data importer script from SMOKE-MOVES Integration| | | |Tool Run Specification Generator| | | || | | |-- SEMAP_??_2007runspec.cshMOVES2010a C-shell eun specification script from SMOKE-MOVES Integration| | | |Tool Run Specification Generator| | | || | | |-- SSCCC_importer_MACHINE_CORE.cshC-shell script to run MOVES2010a data import on a specific MACHINE and CORE| | | || | | |-- SSCCC_runspec_MACHINE_CORE.cshC-shell script to run MOVES2010a run specification on a specific MACHINE and CORE||-- smoke_moves_script(directory) SMOKE-MOVES Integration Tool scripts to generate MOVES2010a XML and| |C-shell scripts| || |-- ??(directories) one directory per state| | || | |-- ??_repcountyRepresentative county definition file forSMOKE-MOVES Integration Tool| | || | |-- ??_runcontrolRun control file for the SMOKE-MOVES Integration Tool| | || | |-- smoke_moves_runspec_generator.cshC-shell script to run the SMOKE-MOVES Integration Tool| || |-- runspec_generator_v0.31_22Mar2011_early_NLEV.pl SMOKE-MOVES Tool Integration perl script for NLEV states (used only for VA)| || |-- runspec_generator_v0.31_22Mar2011.plSMOKE-MOVES Tool Integration perl script

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

41 AMEC 

# 8.0 Conclusion

EPA’s Motor Vehicle Emissions Simulator (MOVES) ver sion 2010a was used in an on-road mobile

source emissions modeling study for thirty-nine rep resentative counties in ten SEMAP states. There

were five distinct components to the effort:

• Perform relative humidity (RH) and Reid vapor pres sure (RVP) sensitivity experiments;

• Estimate MOVES and SMOKE meteorology;

• Estimate on-road mobile source emissions factors u sing MOVES2010a;

• Estimate on-road mobile source emissions using SMO KE; and

• Prepare on-road mobile source emissions estimates summaries from SMOKE reports.

The purpose for conducting the sensitivity experime nts was to determine how responsive the

modeling system was to changes in RH and RVP, the r esults of which were used to help guide the

choice of fuel seasons to model. It was found that for diesel and gasoline VOC, CO, 

# SO

2 

# , PM 10 

# and



# PM 2.5 

# , a + 5% RH change or even a + 10% RH change results in emissions changes that wil l likely

not impact the air quality modeling results. Howev er, for NO X 

# in a typical county, a + 5% RH change

resulted in diesel and gasoline NO X 

# emissions estimates changing by + 1.25 tons/day (+ 1.35% --

note that an increase in RH results in a decrease i n NO X 

# ). Further, it was discovered that the

greatest impact to emissions occurs in an RVP chang e from 15.0 psi to 13.5 psi with CO and VOC

exhibiting definite sensitivity. There is less of an impact to CO and VOC emissions when the RVP

changes from 9.0 psi to 7.8 psi. However, in both cases NO X 

# has about a 1.0 ton/day sensitivity in a

typical county, which may be important for modeling and policy purposes.

Using the MET4MOVES component of the SMOKE-MOVES In tegration Tool, estimates of RH and

ambient temperature for use in MOVES2010a and SMOKE were prepared. The two important

inputs to MET4MOVES were the fuel month cross-refer ence file and the representative county

cross-reference file, both which were developed joi ntly by the study team and SEMAP.

Six additional MOVES2010a input files were develope d by the study team based on information

provided by SEMAP:

• Fuel formulation;

• Fuel supply;

• VMT;

• Inspection and Maintenance (I/M) program;

• Age distribution; and

• Vehicle population.

These data coupled with the meteorology were input to MOVES2010a, which produced the on-road

mobile source emissions factors. The on-road mobil e source emissions factors were subjected to

quality assurance review by the study team, the SEM AP QA contractor (ENVIRON), and

representatives from the SEMAP states. The emissio ns factors and attendant data were delivered

to researchers at UNC who ran SMOKE to estimate on- road mobile source emissions.

Researchers at UNC provided SMOKE reports to the st udy team for use in summarizing the on-road

mobile source emissions estimates. The study team developed Excel workbooks with VBA scripting

to facilitate the ingestion of the SMOKE reports. Further, VBA scripts were developed to prepare a

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

42 AMEC 

# number of standard report summaries as well as to p rovide a limited ad-hoc reporting capability so

that a user of the Excel workbooks can prepare his/ her own report summaries from the SMOKE

reports. Various tabular and graphical reports wer e prepared for use by SEMAP.

# 2007 MOVES2010a On-road Mobile Source Emissions Fac tors for the

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013

43 AMEC 

# 9.0 REFERENCES

Boylan, J., (2010). Final SEMAP MOVES Representati ve Counties. Excel spreadsheet

(SEMAP_Representative Counties4.xls) delivered via email 20-Dec.

EPA, 2010. “User’s Guide for the SMOKE–MOVES Integ ration Tool.” Prepared for: Rich Mason,

U.S. EPA, OAQPS, C339-02, USEPA Mailroom, Research Triangle Park, NC 27711.

Prepared by: B.H. Baek, Institute for the Environme nt, The University of North Carolina at

Chapel Hill, 137 E. Franklin St., CB 6116, Chapel H ill, NC 27599-6116, and Alison

DenBleyker, ENVIRON, 773 San Marin Drive, Suite 211 5, Novato, CA 94998. Contract No:

EP-D-07-102, Work Assignment: 3-03. July 14. www. smoke-model.org/smoke_moves_tool.

HPMS, 2009. National Transportation Atlas Data Bas e. Research and Technology Innovation

Administration, Bureau of Transportation Statistics

. www.bts.gov/publications/national_transportation_at las_database/2009/

HPMS, 2010. National Transportation Atlas Data Bas e. Research and Technology Innovation

Administration, Bureau of Transportation Statistics

. www.bts.gov/publications/national_transportation_at las_database/2010/

NHPN, 2007. The National Highway Planning Network. US Department of Transportation, Federal

Highway Administration. www.fhwa.dot.gov/planning/ nhpn/

ORD, 2009. “Meteorology-Chemistry Interface Prepro cessor Release Notes,” U.S. Environmental

Protection Agency, Office of Research and Developme nt, Research Triangle Park, NC,

October.

OTAQ, 2010a. “Motor Vehicle Emission Simulator (MO VES) 2010a: User Guide,” EPA-420-B-10-

036, U.S. Environmental Protection Agency, Office o f Transportation and Air Quality,

Research Triangle Park, NC, August.

(www.epa.gov/otaq/models/moves/MOVES2010a/420b10036 .pdf)

OTAQ, 2010b. MOVES (Motor Vehicle Emission Simulat or). U.S. Environmental Protection

Agency, Office of Transportation and Air Quality, R esearch Triangle Park, NC, August.

(www.epa.gov/otaq/models/moves/index.htm)

OTAQ, 2010c. Tools for MOVES. .S. Environmental P rotection Agency, Office of Transportation

and Air Quality, Research Triangle Park, NC, Septem ber 8.

www.epa.gov/otaq/models/moves/tools.html